HOUSTON--(BUSINESS WIRE)--PACIFIC COAST OIL TRUST (OTC Pink: ROYTL) (the “Trust”), a royalty trust formed by Pacific Coast Energy Company LP (“PCEC”), announced today that there will be no cash distribution to the holders of its units of beneficial interest of record on February 26, 2021 based on the Trust’s calculation of net profits generated during December 2020 (the “Current Month”) as provided in the conveyance of net profits interests and overriding royalty interest (the “Conveyance”). If the Trust continues to receive insufficient monthly income from its net profits interests and overriding royalty interest, the Trust is expected to terminate by its terms by the end of 2021. As described further below, based on information from PCEC, the likelihood of distributions to the unitholders in the foreseeable future is extremely remote. The Trust may also be terminated upon the occurrence of other events as described in the Trust’s filings with the SEC. All financial and operational information in this press release has been provided to the Trustee by PCEC.

The Current Month’s distribution calculation for the Developed Properties resulted in an operating income of approximately $280,000. Revenues from the Developed Properties were approximately $1.71 million, lease operating expenses including property taxes were approximately $1.42 million, and development costs were approximately $15,000. The average realized price for the Developed Properties was $46.17 per Boe for the Current Month, as compared to $40.11 per Boe in November 2020. Although oil prices have begun to increase since their sharp decline in the first quarter of 2020, prices continued to remain depressed during the Current Month as compared to December 2019. The cumulative net profits deficit amount for the Developed Properties decreased slightly at approximately $25.6 million in the Current Month versus approximately $25.8 million in the prior month.

The Current Month’s calculation included approximately $50,000 generated from the 7.5% overriding royalty interest on the Remaining Properties from Orcutt Diatomite and Orcutt Field. Average realized prices for the Remaining Properties were $43.36 per Boe in the Current Month, as compared to $36.77 per Boe in November 2020. The cumulative net profits deficit for the Remaining Properties decreased by approximately $18,000 and was approximately $2.7 million for the Current Month.

The monthly operating and services fee of approximately $95,000 payable to PCEC and Trust general and administrative expenses of approximately $200,000 together exceeded the payment of approximately $50,000 received from PCEC from the 7.5% overriding royalty interest on the Remaining Properties, creating a shortfall of approximately $245,000.

PCEC has provided the Trust with a $1 million letter of credit to be used by the Trust if its cash on hand (including available cash reserves) is not sufficient to pay ordinary course administrative expenses as they become due. Further, the trust agreement provides that if the Trust requires more than the $1 million under the letter of credit to pay administrative expenses, PCEC will, upon written request of the Trustee, loan funds to the Trust in such amount as necessary to pay such expenses. PCEC has indicated its willingness to begin negotiating the terms of such a loan upon the Trustee’s written request. Under the trust agreement, the Trust may only use funds provided under the letter of credit or loaned by PCEC or another source to pay the Trust’s current accounts or other obligations to trade creditors in connection with obtaining goods or services or for the payment of other accrued current liabilities arising in the ordinary course of the Trust’s business. The Trust will be drawing funds from the letter of credit to pay the expected shortfall of approximately $245,000, which together with prior drawdowns would result in the drawdown of the remaining amount available under the letter of credit. In addition to the funds drawn from the letter of credit, the Trust has outstanding borrowings from PCEC of approximately $276,000, including interest thereon, related to shortfalls from prior months. Consequently, no further distributions may be made to Trust unitholders until the Trust’s indebtedness created by such amounts drawn or borrowed, including interest thereon, has been paid in full.

Sales Volumes and Prices

The following table displays PCEC’s underlying sales volumes and average prices for the Current Month:

Update on Estimated Asset Retirement Obligations

As previously disclosed, in November 2019, PCEC informed the Trustee that, as permitted by the Conveyance, PCEC intended to begin deducting its estimated asset retirement obligations (“ARO”) associated with the West Pico, Orcutt Hill, Orcutt Hill Diatomite, East Coyote and Sawtelle fields, thereby reducing the amounts payable to the Trust under its Net Profits Interests. ARO is the accounting recognition related to plugging and abandonment obligations that all oil and gas operators face. PCEC engaged an accounting firm, Moss Adams LLP (“Moss Adams”), acting as third-party consultants, to assist PCEC in determining its estimated ARO, and on February 27, 2020, PCEC informed the Trustee that based on the analysis performed by Moss Adams, PCEC’s estimated ARO, as of December 31, 2019, is $45,695,643, which is approximately $10.0 million less than the amount that was originally estimated before Moss Adams completed its analysis, as previously disclosed in the Trust’s Current Report on Form 8‑K filed on November 13, 2019. According to PCEC and its third-party consultants, its estimated ARO, which reflects PCEC’s assessment of current market conditions as of December 31, 2019 and changes in California law, was determined to be approximately $33.2 million for the Developed Properties and approximately $12.5 million for the Remaining Properties, or approximately $26.5 million and approximately $3.1 million net to the Trust, respectively, and PCEC has reflected these amounts beginning with the calculation of the net profits generated during January 2020. The accrual has resulted in a current cumulative net profits deficit of approximately $28.4 million, which must be recouped from proceeds otherwise payable to the Trust from the Trust’s Net Profits Interests. Therefore, until the net profits deficit is eliminated, the only cash proceeds the Trust will receive are pursuant to the 7.5% overriding royalty interest.

PCEC has informed the Trustee that in accordance with generally accepted accounting principles, PCEC will evaluate the ARO on a quarterly basis. As a result of that re-evaluation, the actual ARO incurred in the future may be greater or less than the estimated amounts provided by PCEC.

Based on PCEC’s estimate of its ARO attributable to the Net Profits Interest, deductions relating to estimated ARO are likely to eliminate the likelihood of any distributions to Trust unitholders for the foreseeable future, as previously disclosed in the Trust’s Current Report on Form 8-K filed on November 13, 2019.

As previously disclosed, the Trust engaged Martindale Consultants, Inc. (“Martindale”), a provider of analysis and compliance review services to the oil and gas industry, to perform an independent review of the estimated ARO in the Moss Adams report that PCEC provided to the Trustee. The Trustee also has engaged an accounting expert to advise the Trustee regarding the accruals that PCEC has booked relating to its estimated ARO. As disclosed in the Trust’s Current Report on Form 8-K filed on December 29, 2020, Martindale has completed its review of the estimated ARO and on December 21, 2020 provided its analysis and recommendations to the Trustee. Based on Martindale’s recommendations provided in its report to the Trust, as disclosed in the Trust’s Current Report on Form 8-K filed on December 29, 2020, the Trustee requested that PCEC promptly make several adjustments to its calculations and methods of deducting ARO from the proceeds to which the Trust is otherwise entitled pursuant to its Net Profits Interests. The Trustee and PCEC are continuing to discuss these requests and the recommendations of the Martindale report.

As described in more detail in the Trust’s filings with the SEC, the Trust will terminate if the annual cash proceeds received by the Trust from the Net Profits Interests and 7.5% overriding royalty interest total less than $2.0 million for each of any two consecutive calendar years. PCEC is deducting estimated ARO, thereby reducing the amounts payable to the Trust. Unless significant market changes were to occur, no payments will be made by PCEC to the Trust for the foreseeable future, which would result in the total proceeds received by the Trust to total less than $2.0 million in each of 2020 and 2021.

Production Update

PCEC has informed the Trustee that the economic effects of the COVID-19 pandemic and the oversupply of crude oil resulting from the dispute over production levels between Russia and the members of the Organization of Petroleum Exporting Countries have had an adverse impact on PCEC’s production. PCEC continuously evaluates, based on price, whether to curtail production or whether to spend additional amounts to return production from down wells. PCEC has informed the Trustee that unless a substantial number of wells return to production, or oil prices improve significantly or both, any monthly payments that PCEC may make to the Trust may not be sufficient to cover the Trust’s administrative expenses, and therefore the likelihood of distributions to the unitholders in the foreseeable future is extremely remote.

Overview of Trust Structure

Pacific Coast Oil Trust is a Delaware statutory trust formed by PCEC to own interests in certain oil and gas properties in the Santa Maria Basin and the Los Angeles Basin in California (the “Underlying Properties”). The Underlying Properties and the Trust’s net profits, and royalty interests are described in the Trust’s filings with the SEC. As described in the Trust’s filings with the SEC, the amount of any periodic distributions is expected to fluctuate, depending on the proceeds received by the Trust as a result of actual production volumes, oil and gas prices, development expenses, and the amount and timing of the Trust’s administrative expenses, among other factors. For additional information on the Trust, please visit https://royt.q4web.com/home/default.aspx.

Cautionary Statement Regarding Forward-Looking Information

This press release contains statements that are "forward-looking statements" within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended. All statements contained in this press release, other than statements of historical facts, are "forward-looking statements" for purposes of these provisions. These forward-looking statements include estimates of future asset retirement obligations, expectations regarding the impact of deductions for such obligations on future distributions to unitholders, estimates of future total distributions to unitholders in 2021, expectations regarding the impact of COVID-19 on the Trust and the impact of the pandemic on future distributions to unitholders, expectations regarding the impact of lower commodity prices on oil and gas reserve estimates, PCEC’s plans to shut in production or to spend additional amounts to return production from down wells, expectations regarding PCEC’s ability to loan funds to the Trust, and the amount and date of any anticipated distribution to unitholders. In any case, PCEC’s deductions of its estimated asset retirement obligations will have a material adverse effect on distributions to the unitholders and on the trading price of the Trust units and may result in the termination of the Trust. Any anticipated distribution is based, in part, on the amount of cash received or expected to be received by the Trust from PCEC with respect to the relevant period. Any differences in actual cash receipts by the Trust could affect this distributable amount. The amount of such cash received or expected to be received by the Trust (and its ability to pay distributions) has been and will be significantly and negatively affected by prevailing low commodity prices, which have declined significantly, could decline further and could remain low for an extended period of time in light of the economic effects of the COVID-19 pandemic and the dispute over production levels between Russia and the members of the Organization of Petroleum Exporting Countries. Other important factors that could cause actual results to differ materially include expenses related to the operation of the Underlying Properties, including lease operating expenses, expenses of the Trust, and reserves for anticipated future expenses. Statements made in this press release are qualified by the cautionary statements made in this press release. Neither PCEC nor the Trustee intends, and neither assumes any obligation, to update any of the statements included in this press release. An investment in units issued by Pacific Coast Oil Trust is subject to the risks described in the Trust's Annual Report on Form 10-K for the year ended December 31, 2018 filed with the SEC on March 8, 2019, and if applicable, the Trust’s subsequent Quarterly Reports on Form 10-Q. The Trust's Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q are available over the Internet at the SEC's website at http://www.sec.gov.

Pacific Coast Oil Trust
The Bank of New York Mellon Trust Company, N.A., as Trustee
Sarah Newell
1(512) 236-6555

HOUSTON--(BUSINESS WIRE)--Helix Energy Solutions Group, Inc. (NYSE: HLX) announced today that it will be participating in the following upcoming virtual events:

• Credit Suisse 26^th Annual Energy Summit on Tuesday, March 2, 2021
• Raymond James & Associates 42^nd Annual Institutional Investor Conference on Wednesday, March 3, 2021
• Simmons Energy 21^st Annual Energy Conference on Tuesday, March 23, 2021

Any investor presentation provided during the virtual conferences will be publicly available and may be accessed on the “For the Investor” page of Helix’s website, www.HelixESG.com.

About Helix

Helix Energy Solutions Group, Inc., headquartered in Houston, Texas, is an international offshore energy services company that provides specialty services to the offshore energy industry, with a focus on well intervention and robotics operations. For more information about Helix, please visit our website at www.HelixESG.com.

For any questions contact Erik Staffeldt at 281-618-0465 or by email - This email address is being protected from spambots. You need JavaScript enabled to view it.

DALLAS--(BUSINESS WIRE)--Texas Pacific Land Corporation (NYSE: TPL) (the “Company” or "TPL") today announced its financial and operating results for the fourth quarter and full year of 2020.

Conversion of the Trust

As previously announced, on January 11, 2021, we completed our reorganization from a business trust, Texas Pacific Land Trust, into Texas Pacific Land Corporation (the “Corporate Reorganization”), a corporation formed and existing under the laws of the State of Delaware. Any references herein to the Company, TPL, our, we or us with respect to periods prior to January 11, 2021 will be in reference to Texas Pacific Land Trust, and references to periods on that date and thereafter will be in reference to Texas Pacific Land Corporation. Any reference to Sub-share Certificates or Sub-shares are to the Sub-share Certificates of Proprietary Interest of Texas Pacific Land Trust.

Quarterly Dividend Declared

The board of directors (the "Board") has determined to pay dividends quarterly going forward in March, June, September and December of each year, subject to the discretion of the Board. On February 17, 2021, the Board declared a quarterly cash dividend of $2.75 per share payable on March 15, 2021 to stockholders of record at the close of business on March 8, 2021.

Share Repurchases

The Board has also decided that the Company will begin the repurchase of the Company's common stock consistent with TPL's long history of repurchasing Sub-shares. The timing and amount of share repurchases is subject to the discretion of the Board.

Fourth Quarter 2020 Highlights:

• Net income of $44.8 million, or $5.77 per Sub-share Certificate ("Sub-share")

• Revenues of $74.3 million

• EBITDA of $59.0 million ⁽¹⁾

• Cash flows of $45.6 million from operating activities

• Special cash dividend of $10.00 per Sub-share on December 17, 2020, the Company's second special cash dividend in 2020

Full Year 2020 Highlights:

• Net income of $176.0 million, or $22.70 per Sub-share

• Revenues of $302.6 million, the second largest year in our history

• EBITDA of $234.1 million ⁽¹⁾

• Cash flows of $207.0 million from operating activities

• Total dividends of $26.00 per Sub-share, consisting of a regular cash dividend of $10.00 per Sub-share in March 2020, a special cash dividend of $6.00 per Sub-share in March 2020 and a special cash dividend of $10.00 per Sub-share in December 2020.

(1) Reconciliations of Non-GAAP measures are provided in the tables below.

“Despite the challenges presented during 2020, particularly with respect to the oil and gas industry, we continued to generate positive operating results and reported our second largest revenue year in the Company's history,” said Tyler Glover, President and Chief Executive Officer of the Company. “With the completion of our Corporate Reorganization in January 2021, we are eager to begin the next chapter of history as a corporation and anticipate the benefits our new structure affords us.”

Financial Results for the Fourth Quarter of 2020:

The Company reported net income of $44.8 million for the fourth quarter ended December 31, 2020, a decrease of 35.2% compared to net income of $69.1 million for the fourth quarter ended December 31, 2019. Net income for the fourth quarter of 2020 was impacted by decreased revenues, largely driven by a $20.5 million decrease in land sales and a $12.5 million decrease in water sales and royalties. The decrease in revenue was partially offset by a $6.1 million decrease in operating expenses over the same time period.

Revenues across all revenue streams were lower for the fourth quarter of 2020 compared to the same period of 2019. Land sales for the fourth quarter of 2019 included a $22.0 million land exchange. There were no significant land transactions during the fourth quarter of 2020. Our revenues from land sales are subject to substantial fluctuation and vary from year to year. The decrease in water sales for the fourth quarter of 2020 compared to 2019 is principally due to a 22.8% decrease in the average sales price per barrel of water over the same time period. Additionally, the fourth quarter of 2020 was impacted by an approximately $7.0 million deferral of water sales revenue related to take or pay contracts.

Operating expenses decreased approximately $6.1 million during the fourth quarter of 2020 compared to the same period of 2019. The decreases were principally related to a $4.9 million decrease in incentive compensation expense, a $2.4 million decrease in water service-related expenses resulting from cost savings measures implemented during 2020 and a $1.8 million reduction in contract labor expense. These decreases were partially offset by a $2.6 million increase in legal and professional fees, primarily resulting from our Corporate Reorganization.

Financial Results for the Year Ended December 31, 2020:

The Company reported net income of $176.0 million for the year ended December 31, 2020, a decrease of 44.8% compared to net income of $318.7 million for the year ended December 31, 2019, which included a $100 million land sale. Net income for the year ended December 31, 2020 was principally impacted by decreased land sales and decreased water sales and royalties. Excluding the impact of the 2019 land sale (net of income tax), net income for the year ended December 31, 2019 was $239.7 million.

Revenues for the year ended December 31, 2020 were $302.6 million compared to $490.5 million for the comparable period of 2019. All revenue streams for the year ended December 31, 2020 were lower than for the same period of 2019. Revenues were negatively impacted by the economic impacts related to the COVID-19 pandemic and the declines in demand and crude oil prices that occurred during 2020. Many of our revenue streams are impacted by the capital decisions made by companies that operate in the areas where we own land. The most significant impact on our revenues related to decreased land sales for the year ended December 31, 2020 compared to 2019. Revenues for 2019 included a $100 million land sale. We had no comparable land sales in 2020. Water sales decreased $23.7 million for the year ended December 31, 2020 compared to 2019, principally due to an 18.7% decrease in the average sales price per barrel of water, a 6.8% decrease in the number of barrels sold and a $7.0 million deferral of water sales revenue during the fourth quarter related to take or pay contracts. Additionally, water royalties decreased $6.4 million over the same time period.

Operating expenses for the year ended December 31, 2020 were approximately $5.6 million lower than the same period of 2019. The decrease is principally the result of a decrease of $6.6 million of water-related expenses resulting from cost savings measures implemented during 2020 and decreased legal and professional fees.

COVID-19 Pandemic and Market Conditions Update

The increased supply of oil and gas by member nations of OPEC+ and the uncertainty caused by the global spread of COVID 19 led to declines in crude oil prices and a reduction in global demand for oil and gas in 2020. The full impact of these events, which resulted in production curtailments and/or conservation of capital by the owners and operators of the oil and gas wells to which the Company’s royalty interests relate, is unknown at this time. These events have negatively affected the Company’s business and results of operations for the year ended December 31, 2020.

During these uncertain times, we have continued to generate positive operating results and remain focused on meeting the operational needs of our customers while maintaining a safe and healthy work environment for our employees. Our existing information technology infrastructure has afforded us the opportunity to allow our corporate employees to work remotely. We have deployed additional safety and sanitization measures, including quarantine facilities for our field employees, if needed.

In an effort to decrease ongoing operational costs, we have implemented certain cost reduction measures which include, but are not limited to, a reduction in contract labor, conversion of portions of our water sourcing infrastructure to electric power and negotiated price reductions and discounts with certain vendors. We continue to monitor our customer base and outstanding accounts receivable balances as a means of minimizing any potential collection issues. As a royalty owner, we have no capital expenditure or operating expense burden for development of wells. Furthermore, our water operations currently have limited capital expenditure requirements, the amount and timing of which are entirely within our control.

About Texas Pacific Land Corporation

Texas Pacific Land Corporation is one of the largest landowners in the State of Texas with approximately 880,000 acres of land in West Texas. The Company is not an oil and gas producer, but its surface and royalty ownership allow revenue generation through the entire value chain of oil and gas development, including through fixed fee payments for use of our land, revenue for sales of materials (caliche) used in the construction of infrastructure, providing sourced water and treated produced water, revenue from our oil and gas royalty interests, and revenues related to saltwater disposal on our land. The Company also generates revenue from pipeline, power line and utility easements, commercial leases, material sales and seismic and temporary permits related to a variety of land uses including midstream infrastructure projects and hydrocarbon processing facilities.

Visit TPL at www.texaspacific.com.

Cautionary Statement Regarding Forward-Looking Statements

This news release may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, that are based on TPL’s beliefs, as well as assumptions made by, and information currently available to, TPL, and therefore involve risks and uncertainties that are difficult to predict. Generally, future or conditional verbs such as “will,” “would,” “should,” “could,” or “may” and the words “believe,” “anticipate,” “continue,” “intend,” “expect” and similar expressions identify forward-looking statements. Forward-looking statements include, but are not limited to, statements regarding the Corporate Reorganization and other references to strategies, plans, objectives, expectations, intentions, assumptions, future operations and prospects and other statements that are not historical facts. You should not place undue reliance on forward-looking statements. Although TPL believes that plans, intentions and expectations, including those regarding the Corporate Reorganization, reflected in or suggested by any forward-looking statements made herein are reasonable, TPL may be unable to achieve such plans, intentions or expectations and actual results, and performance or achievements may vary materially and adversely from those envisaged in this news release due to a number of factors including, but not limited to: an inability to achieve some or all of the expected benefits of the Corporate Reorganization and distribution; potential adverse reactions or changes to business relationships resulting from the announcement or completion of the Corporate Reorganization; the potential impacts of COVID-19 on the global and U.S. economies as well as on TPL’s financial condition and business operations; the initiation or outcome of potential litigation; and any changes in general economic and/or industry specific conditions. These risks, as well as other risks associated with TPL and the Corporate Reorganization are also more fully discussed in a Current Report on Form 8-K filed by TPL with the SEC on December 31, 2020, which includes an information statement describing the Corporate Reorganization and the distribution in more detail. You can access TPL’s filings with the SEC through the SEC website at www.sec.gov and TPL strongly encourages you to do so. Except as required by applicable law, TPL undertakes no obligation to update any forward-looking statements or other statements herein for revisions or changes after this communication is made.

NON-GAAP PERFORMANCE MEASURES AND DEFINITIONS

In addition to amounts presented in accordance with generally accepted accounting principles in the United States of America (“GAAP”), we also present certain supplemental non-GAAP measurements. These measurements are not to be considered more relevant or accurate than the measurements presented in accordance with GAAP. In compliance with requirements of the Securities and Exchange Commission (“SEC”), our non-GAAP measurements are reconciled to net income, the most directly comparable GAAP performance measure. For all non-GAAP measurements, neither the SEC nor any other regulatory body has passed judgment on these non-GAAP measurements.

EBITDA

EBITDA is a non-GAAP financial measurement of earnings before interest, taxes, depreciation, depletion and amortization. Its purpose is to highlight earnings without finance, taxes, and depreciation, depletion and amortization expense, and its use is limited to specialized analysis. We have presented EBITDA because we believe that it is a useful supplement to net income as an indicator of operating performance.

The following table presents a reconciliation of net income to EBITDA for the three months and years ended December 31, 2020 and 2019 (in thousands):

Chris Steddum
Vice President, Finance and Investor Relations
(214) 969-5530

AUSTIN, Texas--(BUSINESS WIRE)--USA Compression Partners, LP (NYSE: USAC) (“USA Compression”) today announced that its 2020 tax packages, including the Schedule K-1, are now available online and may be accessed at taxpackagesupport.com/usac. USA Compression has begun the process of mailing the 2020 tax packages to unitholders. Unitholders may call Tax Package Support at 1-855-521-8151 or browse USA Compression’s website at usacompression.com in the Investor Relations section under K-1 Information.

About USA Compression Partners, LP

USA Compression Partners, LP is a growth-oriented Delaware limited partnership that is one of the nation’s largest independent providers of natural gas compression services in terms of total compression fleet horsepower. USA Compression partners with a broad customer base composed of producers, processors, gatherers and transporters of natural gas and crude oil. USA Compression focuses on providing natural gas compression services to infrastructure applications primarily in high-volume gathering systems, processing facilities and transportation applications. More information is available at usacompression.com.

USA Compression Partners, LP
Nelson Larkin, Tax Director
(512) 369-1604
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TULSA, Okla.--(BUSINESS WIRE)--Williams (NYSE: WMB) announced today that it has priced a public offering of $900 million of its 2.600% Senior Notes due 2031 at a price of 99.631 percent of par. The expected settlement date for the offering is March 2, 2021, subject to customary closing conditions.

Williams intends to use the net proceeds of the offering to repay its $500 million of 4.00% Senior Notes due 2021 and its $371 million of 7.875% Senior Notes due 2021 and for general corporate purposes.

RBC Capital Markets, LLC, Mizuho Securities USA LLC, MUFG Securities Americas Inc. and TD Securities (USA) LLC are acting as joint book-running managers for the offering.

This news release is neither an offer to sell nor a solicitation of an offer to buy any of these securities and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offer, solicitation or sale is unlawful.

An automatic shelf registration statement relating to the notes was previously filed with the Securities and Exchange Commission (the “SEC”) and became effective upon filing. Before you invest, you should read the prospectus in the registration statement and other documents Williams has filed with the SEC for more complete information about Williams and the offering. A copy of the prospectus supplement and prospectus relating to the offering may be obtained on the SEC website at www.sec.gov or from any of the underwriters by contacting:

RBC Capital Markets, LLC
200 Vesey Street, 8^th Floor
New York, NY 10281
Attention: DCM Transaction Management
Telephone: 1-866-375-6829

Mizuho Securities USA LLC
1271 Avenue of the Americas, 3^rd Floor
New York, NY 10020
Attention: Debt Capital Markets Desk
Telephone: 1-866-271-7403

MUFG Securities Americas Inc.
1221 Avenue of the Americas, 6^th Floor
New York, NY 10020
Attention: Capital Markets Group
Telephone: 1-877-649-6848

TD Securities (USA) LLC
1 Vanderbilt Avenue, 12^th Floor
New York, NY 10017
Attention: Transaction Management Group
E-mail: This email address is being protected from spambots. You need JavaScript enabled to view it.
Telephone: 1-855-495-9846

About Williams
Williams (NYSE: WMB) is committed to being the leader in providing infrastructure that safely delivers natural gas products to reliably fuel the clean energy economy. Headquartered in Tulsa, Oklahoma, Williams is an industry-leading, investment grade C-Corp with operations across the natural gas value chain including gathering, processing, interstate transportation and storage of natural gas and natural gas liquids. With major positions in top U.S. supply basins, Williams connects the best supplies with the growing demand for clean energy. Williams owns and operates more than 30,000 miles of pipelines system wide – including Transco, the nation’s largest volume and fastest growing pipeline – and handles approximately 30 percent of the natural gas in the United States that is used every day for clean-power generation, heating and industrial use.

Portions of this document may constitute “forward-looking statements” as defined by federal law. Although Williams believes any such statements are based on reasonable assumptions, there is no assurance that actual outcomes will not be materially different. Any such statements are made in reliance on the “safe harbor” protections provided under the Private Securities Reform Act of 1995. Additional information about issues that could lead to material changes in performance is contained in Williams’ annual and quarterly reports filed with the SEC.

MEDIA:
This email address is being protected from spambots. You need JavaScript enabled to view it.
(800) 945-8723

INVESTOR CONTACT:
Danilo Juvane
(918) 573-5075

Already recognized as the world leader in robotic solutions for the solar industry, Ecoppia signed an agreement with an international energy company for the deployment of its robotic solutions in BenBan Solar Park, Egypt

TEL AVIV, Israel--(BUSINESS WIRE)--Ecoppia (TASE:ECPA), the pioneer and world leader in robotic solutions for photovoltaic solar, announced today a new project in one of the worlds’ largest solar parks in BenBan, Egypt.

BenBan solar park, located near the southern Egyptian city of Aswan, has a total capacity of 1,650 MWp corresponding to an annual production of approximately 3.8 TW, and is spread across nearly 40 km. While enjoying very high radiation rates, the facility also suffers from major soiling and desert sands, requiring frequent cleaning to ensure steady and optimal production.

Ecoppia’s robotic solutions were proven to be extremely effective, cleaning nearly 10 million solar panels every night in harsh climatic conditions, spreading across roughly 2,500MW of installations globally.
Not only effective, the robots were also proven to be fully safe and reliable on all module types, to include glass on glass and bifacial.

Ecoppia’s unique robotic solutions are completely autonomous, water-free and energy independent, allowing site owners to enjoy the benefits of a year-round peak performance while lowering their O&M expenses and overall, their LCOE.

This project in BenBan will feature the light weighted Ecoppia T4 solution, designed especially for Single Axis trackers.

This is yet another vote of confidence in Ecoppia by leading multinational energy company, following the long-term engagements already in place with market leaders such as Engie, EDF, First Solar, Fortum, ReNew Power, Azure Power and others.

“We are excited to take part in the sustainability revolution in the Middle East” said Jean Scemama, CEO of Ecoppia. “As leaders in robotic cleaning solutions for solar, entering a new country is a great milestone in the company’s growth, especially when the project is in one of the largest and most significant solar parks in the world” he added.
“Our unparalleled experience in the region, operating in the Middle East since early 2014, enables us to deliver great value to such projects, as we see more and more energy companies advancing towards full automation of their O&M activities” he concluded.

About Ecoppia

With over 16GW of signed agreements, Ecoppia (TASE: ECPA) is a pioneer and world leader in robotic solutions for photovoltaic solar. Ecoppia’s cloud-based, water-free, autonomous robotic systems remove dust from solar panels on a daily basis leveraging sophisticated technology and advanced Business Intelligence capabilities. Remotely managed and controlled, the Ecoppia platform allows solar sites to maintain peak performance with minimal costs and human intervention. Ecoppia’s proprietary algorithms and robotic solutions make day-to-day O&M at solar sites safer, more efficient and more reliable. Publicly held and backed by prominent international investment funds, Ecoppia works with the largest energy companies across the globe, cleaning millions of solar panels every day. For more information, please visit www.ecoppia.com

Anat Cohen Segev
VP Marketing, Ecoppia
This email address is being protected from spambots. You need JavaScript enabled to view it.

Diverse supply chain spending up 100 percent in five years

CHICAGO--(BUSINESS WIRE)--Charter members of the Illinois Utilities Business Diversity Council (IUBDC) spent a combined total of $1.8 billion on goods and services provided by minority-owned, women-owned, and veteran-owned businesses in 2019, a 100 percent increase since the coalition was formed in 2015.

“Diverse suppliers are playing a major role in the efforts of Illinois utilities to modernize energy infrastructure and support the transition to clean energy, drive continuous improvement and meet the evolving needs of customers,” said Joe Dominguez, CEO of ComEd and 2021 Chairman of the IUBDC Board of Directors. “Investing in a diverse supply chain also helps us lift up communities in need, which is more important than ever. Many of the equity issues that we face today can be traced back to the lack of jobs and economic opportunities and that’s an area where Illinois utilities are committed to making a positive impact.”

ComEd, along with Ameren Illinois, Peoples Gas and North Shore Gas, Nicor Gas, and Illinois American Water formed IUBDC to increase business opportunities for diverse companies through closer collaboration, technical development, and sharing of best practices. Since 2014, all electric, gas and water companies under the jurisdiction of the Illinois Commerce Commission with at least 100,000 customers report annually in April on their procurement goals and actual spending with diverse suppliers. Final tallies could top $2 billion for 2020, according to Charles Matthews, president and CEO, Peoples Gas and North Shore Gas, who passed the IUBDC chairman’s gavel to Dominguez in December.

“Our passion for diversity is exemplified not only by our supply chain and our own work forces, but by the formation of the IUBDC,” said Matthews. “We launched this organization not because of a statutory requirement, but because we saw an opportunity to join forces and engage in a systematic effort to expand the opportunities for diverse companies to succeed for the long haul.”

The Will Group, a Chicago-based electrical equipment company established in 1986 by entrepreneur Stephen L. Davis, chairman, works with multiple utilities and is seeing doors open to new business since becoming involved with the IUBDC. The company is playing a key role in ComEd’s deployment of voltage optimization (VO), an energy efficiency solution that controls and lowers the voltage delivered to electric utility customers, reducing energy costs and lowering carbon emissions. The Will Group recently opened a new 60,000-square-foot facility in the North Lawndale neighborhood on Chicago’s West Side, where the company will provide 100 jobs. Josh Davis, president of The Will Group, is a recipient of the IUBDC scholarship to attend the Advanced Management Education Program at Northwestern University’s Kellogg School of Management, in partnership with the National Minority Supplier Development Council.

Accelerated growth in Illinois utility company spending with diverse suppliers began with the Energy Infrastructure Modernization Act (EIMA) or “Smart Grid Bill” enacted in 2011, and the Natural Gas Consumer, Safety & Reliability Act of 2013. These initiatives created unprecedented opportunities for more diverse suppliers to support utility efforts by implementing massive upgrades to aging energy infrastructure and installing new technologies and equipment to improve reliability and service.

For more information about the IUBDC, visit iubdc.com.

About the Illinois Utilities Business Diversity Council

The Illinois Utilities Business Diversity Council (IUBDC) members include Ameren Illinois, ComEd, Illinois American Water, Nicor Gas, North Shore Gas and Peoples Gas. The mission of the IUBDC is to serve the Illinois utilities as a forum for best practice sharing and information exchange with the focus on advancing the growth and utilization of utility-based diverse businesses in the state of Illinois.

Illinois Utilities Business Diversity Council
312-213-8588

Software company reveals record-high collaboration between users in annual benchmarking report

BOSTON--(BUSINESS WIRE)--#climate--Raptor Maps, a leading provider of solar lifecycle management software, released its third annual report on causation and frequency of PV system underperformance. The company utilized its solar data model to query 22 GW of utility-scale and C&I PV systems across 27 countries.

This report leveraged data collected by aerial inspection, a technique specified by owners and operators for commissioning, preventative maintenance, and warranty inspections. Aerial inspection fuses site-specific schematics with thermal and color image data captured under specific conditions by unmanned or manned aircraft.

The results are available for download here.

“This year, we were surprised that each online report was shared to an average of 22 additional users,” reveals Nikhil Vadhavkar, co-founder and CEO of Raptor Maps. “The data owners are authorizing more counterparties to access raw and synthesized data. In particular, we have seen an increased willingness from module manufacturers and EPCs to leverage this data to provide owners and operators with positive resolutions.”

The study encompassed over 70 million modules, 92 module manufacturers, and 1,126 PV systems. On average, Raptor Maps inspections revealed that 1.9% of power production is affected, compared with 1.6% from the previous year. Classifications included in the study include functional units, such as off-nominal inverters and trackers, environmental conditions, such as shading and soiling, and module-level findings, such as cracking and activated bypass diodes.

The global report comes on the heels of a BloombergNEF (BNEF) report forecasting up to 209 GW of new solar PV installations in 2021. 84% of the modules analyzed in the Raptor Maps report are classified as BNEF Tier One. Industry tailwinds include net zero targets from governments and corporations, a stable supply chain, and overall favorable levelized cost of energy (LCOE). Due to this growth, developers, owners, and operators have increasingly required software and data-driven analytics to meet their financial objectives at scale.

For more information, visit raptormaps.com. Technical information regarding data collection protocols, sample contracts, and API documentation is available at docs.raptormaps.com.

About: Raptor Maps is a leading provider of solar lifecycle management software. The company has provided required data products to owners, builders, and operators of over 40 GW of PV systems across 38 countries. It was founded by MIT engineers in 2015, and raised Series A financing in late 2020. Raptor Maps’ mission is to enable the solar industry to scale using software. For more information, visit raptormaps.com.

Nikhil Vadhavkar
Raptor Maps, Inc.
(617) 539-6357

Strategic transformation delivers material free cash flow in 2021; Company to further reduce debt

SPRING, Texas--(BUSINESS WIRE)--Southwestern Energy Company (NYSE: SWN) today announced financial and operating results for the fourth quarter and full year 2020 and issued 2021 guidance.

“In 2020, Southwestern Energy delivered on its commitments, exceeding expectations on all key metrics while navigating the uncertainties of a global pandemic and the associated challenging commodity price and operating environments. We have positioned the Company to deliver material free cash flow going forward through an enduring conviction to our returns-driven strategy. We delivered strong results across all of our strategic pillars, including an accretive acquisition, a meaningfully lower cost structure and an increased underlying asset value,” said Bill Way, Southwestern Energy President and Chief Executive Officer.

“Southwestern Energy has entered 2021 with greater scale and resilience, prepared to capture increasing value from more than one trillion cubic feet equivalent of expected annual production flowing into diverse and key markets. The free cash flow we expect to deliver this year will be used to reduce debt as we progress towards our goal of sustainable 2 times leverage. Consistent with our disciplined approach, any further improvement in cash flow from higher commodity prices will accelerate the delivery of that objective,” Way continued.

2020 Highlights

• Completed acquisition of Montage Resources, delivering over $30 million in G&A synergies, while maintaining balance sheet strength through associated capital market transactions;
• Delivered $55 million of free cash flow in the fourth quarter;
• Realized $90 million in additional expense reductions including a 33% decrease in G&A to $0.12 per Mcfe;
• Reported total production of 880 Bcfe; 3.05 Bcfe per day pro forma fourth quarter net production rate;
• Invested capital of $899 million and delivered 100 wells to sales;
• Generated $362 million of realized hedge gains, including $76 million from basis;
• Repurchased $107 million of senior notes for $72 million, a 33% discount;
• Enhanced liquidity with borrowing base increased to $2.0 billion following acquisition;
• Reduced well costs, averaged $637 per lateral foot in the second half of 2020; annual reduction of 19% to $670 per lateral foot with an average lateral length of 12,154 feet;
• Lowered Proved Developed F&D costs by 25% to $0.40 per Mcfe through well cost reductions and increased well productivity;
• Realized 26% of WTI on full year NGL prices, above the high end of guidance, and 36% of WTI in the fourth quarter, both associated with strengthening market fundamentals and NGL marketing optimization;
• Reported proved reserves of 12.0 Tcfe, including 1.4 Tcfe of positive performance revisions and 741 Bcfe of reserve additions, partially mitigating the impact of backward-looking SEC prices;
• Released our 7^th annual corporate responsibility report; key environmental highlights included top quartile GHG and methane intensity among AXPC peers; and
• Recorded the fifth consecutive year of freshwater neutrality; have now replaced over 14 billion gallons of freshwater in communities where we work and live.

2021 Guidance

The Company’s 2021 guidance is underpinned by the four pillars of its shareholder returns driven strategy: creating sustainable value, protecting financial strength, increasing scale and progressing best-in-class execution. The 2021 plan prioritizes free cash flow generation, disciplined investment at maintenance levels and debt reduction. Highlights are presented below; full guidance is available in the attachments to this press release.

• Guidance based on $2.77 per Mcf NYMEX Henry Hub and $50 per barrel WTI; expect to deliver free cash flow of over $275 million, which is expected to be utilized for debt reduction;
• Prices of $3.00 per Mcfe NYMEX Henry Hub and $58 per barrel WTI would increase free cash flow estimate to more than $375 million and results in achieving targeted leverage ratio of 2.0x;
• Capital investment of $850 to $925 million; expect 3.05 Bcfe per day average fourth quarter 2021 net production, flat with fourth quarter 2020;
• Estimate 75 to 90 wells to sales including 12 to 15 in dry gas Ohio Utica; approximately 50% of total capital investment in dry gas and 50% in liquids-rich acreage;
• Continued focus on costs, expect G&A per Mcfe to decrease 20%;
• Expected to reduce well costs another 10% to an average of approximately $600 per lateral foot for all wells to sales inclusive of Ohio Utica; expect average lateral length of 14,000 feet;
• Hedges in place for approximately 85%, 60% and 95% of expected natural gas, natural gas liquids and oil production, respectively; approximately 80% of natural gas hedges allow for participation in upside from improving prices;
• Protecting 75% of natural gas basis through physical and financial basis hedges and out of basin transportation portfolio; expect financial basis hedge gain of $0.07 to $0.09 per Mcf; and
• Continued commitment to corporate responsibility, investing in human capital and our communities, and developing energy responsibly with a focus on reduced air emissions and water conservation, including maintaining top quartile performance in the industry for GHG and methane intensity.

2020 Fourth Quarter and Full Year Results

1. Capital investments on the cash flow statement include decreases of $5 million and $18 million for the three months ended December 31, 2020 and 2019, respectively, and a decrease of $3 million and an increase of $34 million for the year ended December 31, 2020 and 2019, respectively, relating to the change in accrued expenditures between periods.

Fourth Quarter 2020 Financial Results

For the quarter ended December 31, 2020, Southwestern Energy recorded a net loss of $92 million, or ($0.14) per diluted share, including $335 million of non-cash impairments and a $134 million non-cash gain on unsettled mark to market derivatives. This compares to net income of $110 million, or $0.20 per diluted share in the fourth quarter of 2019.

Adjusted net income (non-GAAP), which excludes non-cash items noted above and other one-time charges, was $119 million or $0.18 per diluted share in 2020 and $99 million or $0.18 per share for the same period in 2019. The increase was primarily related to increased production volumes and a decrease in average unit operating costs, partially offset by wider natural gas basis differentials. For the fourth quarter of 2020, adjusted EBITDA (non-GAAP) was $276 million, net cash provided by operating activities was $121 million and net cash flow (non-GAAP) was $249 million, resulting in $55 million in free cash flow.

As indicated in the table below, fourth quarter 2020 weighted average realized price, including $0.37 per Mcfe of transportation expenses, was $1.93 per Mcfe before the impact of derivatives, down 9% compared to $2.12 per Mcfe in 2019. The decrease was primarily due to widened basis differentials in the Appalachia basin. Fourth quarter weighted average realized price before transportation expense was $2.30 per Mcfe.

The Company realized $52 million in cash-settled derivative gains during the fourth quarter of 2020, a $0.21 per Mcfe uplift. Included in the fourth quarter settled derivative gains is a $47 million gain related to natural gas basis hedges, which protected the Company from widening basis differentials.

Full Year 2020 Financial Results

The Company recorded a net loss of $3.1 billion, or ($5.42) per share, for the year ended December 31, 2020 compared to net income of $891 million, or $1.65 per share in 2019. In 2020, the Company recorded non-cash impairments of $2.8 billion and $138 million of non-cash loss on unsettled derivatives, and had an $818 million change in its deferred tax provision. Excluding these non-cash and other one-time items, adjusted net income for 2020 was $221 million, or $0.38 per share, compared to $328 million, or $0.61 per share, in 2019. The decrease in adjusted net income compared to prior year was primarily the result of a decrease in commodity prices, partially offset by a $182 million increase in settled derivatives impact, increased production volumes and decreased G&A and depreciation, depletion and amortization expense. In 2020, Adjusted EBITDA (non-GAAP) was $742 million, net cash provided by operating activities was $528 million and net cash flow (non-GAAP) was $662 million.

For the full year 2020, weighted average realized price, including $0.37 per Mcfe of transportation expense, was $1.53 per Mcfe before the impact of derivatives, a 30% decrease compared to $2.18 per Mcfe in 2019, due to decreased prices across all commodities. In 2020, the weighted average realized price before transportation expenses was $1.90 per Mcfe.

Cash-settled derivative gains totaled $362 million in 2020, a $0.41 per Mcfe uplift, bringing the weighted average realized price including the impact of derivatives to $1.94 per Mcfe in 2020, compared to $2.42 per Mcfe in 2019.

As of December 31, 2020, Southwestern Energy had total debt of $3.15 billion and a cash balance of $13 million. At the end of 2020, the Company had $700 million of borrowings under its $2.0 billion revolving credit facility with $233 million in outstanding letters of credit.

1. Based on last day monthly futures settlement prices.
2. This discount includes a basis differential, a heating content adjustment, physical basis sales, third-party transportation charges and fuel charges, and excludes financial basis derivatives.

Operational Review

Total production for the quarter ended December 31, 2020 was 257 Bcfe, comprised of 81% natural gas, 16% NGLs and 3% oil. Included in the fourth quarter 2020 results was 49 days of production from the acquired Montage Resources properties. Production totaled 880 Bcfe for the year ended December 31, 2020.

Capital investments in the fourth quarter of 2020 were $194 million, bringing full year capital investment to $899 million. The Company brought 100 wells to sales, drilled 98 wells and completed 96 wells during the year.

1. Excludes $38 million and $41 million in Montage acquisition-related expenses and $4 million and $16 million in restructuring charges for the three months and year ended December 31, 2020, respectively. Excludes $1 million of legal settlement charges for the year ended December 31, 2020.
2. Excludes restructuring charges of $2 million and $11 million and legal settlement charges of $3 million and $6 million for the three months and year ended December 31, 2019, respectively. Excludes a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building for the year ended December 31, 2019.

Southwest Appalachia – In the fourth quarter, total production was 132 Bcfe, with liquids production of 91 MBbls per day, including 49 days of production from properties previously owned by Montage Resources. The Company drilled 10 wells, completed 11 wells and placed 16 wells to sales, excluding four wells placed to sales that were drilled and completed by Montage Resources. The average lateral length of wells to sales was 15,477 feet, and included five wells in the rich area and 11 wells in the super rich area. All five of the rich wells were online for at least 30 days and had an average 30-day rate of 23.2 MMcfe per day, while only six of the super rich wells were online for at least 30 days and had an average 30-day rate of 9.8 MMcfe per day, including 72% liquids.

In 2020, Southwest Appalachia’s total production was 407 Bcfe, including 85 MBbls per day of liquids. The Company drilled 49 wells, completed 52 wells and placed 55 wells to sales during 2020, with 14 drilled uncompleted wells as of December 31, 2020.

Northeast Appalachia – In the fourth quarter, total production was 125 Bcf. There were four wells drilled, seven wells completed and 11 wells placed to sales in the quarter with an average lateral length of 14,667 feet. Of the 11 wells to sales, eight wells were online for at least 30 days and had an average 30-day rate of 15.6 MMcf per day.

Production for the year was 473 Bcf in Northeast Appalachia. The Company drilled 49 wells, completed 44 wells and brought 45 wells to sales during 2020, with 10 drilled uncompleted wells at year-end.

1. Excludes 4 wells placed to sales during the fourth quarter of 2020 that were drilled and completed by Montage Resources.

2020 Proved Reserves

The Company reported total proved reserves of 12.0 Tcfe at year-end 2020, compared to 12.7 Tcfe in 2019. Reserves consisted of 76% natural gas and 24% liquids. During 2020, the Company reported 1.4 Tcfe of positive performance revisions related to increased well performance and lower operating costs, 741 Bcfe of reserve additions, and also acquired 2.4 Tcfe of reserves related to the acquisition of Montage Resources. The Company incurred 4.4 Tcfe of downward price revisions related to significantly reduced trailing 12-month SEC prices on all commodities.

Lower SEC prices, which were $1.98 per Mcf NYMEX Henry Hub, $39.57 per Bbl WTI and $10.27 per Bbl NGLs, resulted in a PV-10 of $1.85 billion. Using 2021 strip prices as of January 4, 2021, which were $2.70 per Mcf NYMEX Henry Hub, $47.67 per Bbl WTI and $11.82 per Bbl NGLs, the PV-10 of the reported year-end 2020 reserves would increase to $5.85 billion, without consideration of any PV-10 increase from the expected higher reserve volumes at those prices.

1. Other includes properties outside of the Appalachian Basin.

The Company’s 2020 proved developed finding and development (PD F&D) costs decreased 25% from the prior year to $0.40 per Mcfe, when excluding the impact of capitalized interest and portions of capitalized G&A costs in accordance with the full cost method of accounting.

Note: Amounts may not add due to rounding

1. Adjusting for the impacts of the full cost accounting method for comparability.
2. Includes increased reserve estimates of 144 Bcfe in the Appalachian Basin associated with productivity enhancements for newly developed PUD locations.

Conference Call

Southwestern Energy will host a conference call and webcast on Friday, February 26, 2021 at 9:30 a.m. Central to discuss fourth quarter and fiscal year 2020 results. To participate, dial US toll-free 877-883-0383, or international 412-902-6506 and enter access code 3652399. The conference call will webcast live at www.swn.com.

To listen to a replay of the call, dial 877-344-7529, International 412-317-0088, or Canada Toll Free 855-669-9658. Enter replay access code 10152130. The replay will be available until March 26, 2021.

Due to the inclement weather last week, the Company plans to file its Annual Report on Form 10-K on March 1, 2021.

About Southwestern Energy

Southwestern Energy Company is an independent energy company engaged in natural gas, natural gas liquids and oil exploration, development, production and marketing. For additional information, visit our website www.swn.com.

Forward Looking Statement

Certain statements and information herein may constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. The words “believe,” “expect,” “anticipate,” “plan,” “intend,” “foresee,” “should,” “would,” “could,” “attempt,” “appears,” “forecast,” “outlook,” “estimate,” “project,” “potential,” “may,” “will,” “are likely,” “guidance,” “goal,” “model,” “target,” “budget” and other similar expressions are intended to identify forward-looking statements, which are generally not historical in nature. Statements may be forward looking even in the absence of these particular words. Examples of forward-looking statements include, but are not limited to, statements regarding the financial position, business strategy, production, reserve growth and other plans and objectives for our future operations, and generation of free cash flow. These forward-looking statements are based on our current expectations and beliefs concerning future developments and their potential effect on us. The forward-looking statements contained in this document are largely based on our expectations for the future, which reflect certain estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions, operating trends, and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. As such, management’s assumptions about future events may prove to be inaccurate. For a more detailed description of the risks and uncertainties involved, see “Risk Factors” in our most recently filed Annual Report on Form 10-K, subsequent Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and other SEC filings. We do not intend to publicly update or revise any forward-looking statements as a result of new information, future events, changes in circumstances, or otherwise. These cautionary statements qualify all forward-looking statements attributable to us, or persons acting on our behalf. Management cautions you that the forward looking statements contained herein are not guarantees of future performance, and we cannot assure you that such statements will be realized or that the events and circumstances they describe will occur.

Investor Contact
Brittany Raiford
Director, Investor Relations
(832) 796-7906
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Bernadette Butler
Investor Relations Advisor
(832) 796-6079
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DUBLIN--(BUSINESS WIRE)--The "Offshore Air Handling Units Market Size, Market Share, Application Analysis, Regional Outlook, Growth Trends, Key Players, Competitive Strategies and Forecasts, 2020 To 2028" report has been added to ResearchAndMarkets.com's offering.

This report offers strategic insights into the global air handling units market with a focus on the offshore applications along with the market size and estimates for the duration 2018 to 2028. The said research study covers an in-depth analysis of multiple market segments based on product types, capacity, applications, and cross-sectional study across different geographies. The study covers the comparative analysis of different segments for the years 2019 & 2028. The report also provides a prolific view on market dynamics such as market drivers, restraints, and opportunities.

Due to harsh environmental conditions observed in offshore applications, it becomes essential to use air handling units manufactured using corrosion-resistant and light-weight materials. Air handling units, also referred to as air handler, acts as lungs of the overall HVAC system and hence becomes a crucial component of the overall system. In offshore applications, the major concern is to protect the air handling units from salty air, rain and stormy weather aboard the offshore facilities. Anoffshore air handling unit is typically designed in a large metal frame (typically made of aluminum) comprising various components such as fans, filters, heating/cooling elements, silencers, and dampers. The outer box is made up of stainless, steel galvanized steel, or aluminum alloys in order to ensure better environmental protection.

Air handling units are commonly used across various applications including oil rigs, cargo ships, cruise liners, navy ships, and other marine applications. With the overall rising offshore industry worldwide, the demand for air handling units in the sector is estimated to remain strong in the following years. This is the prime factor bolstering the offshore air handling unit market growth. Due to rising efforts by the manufacturers towards providing energy-efficient, light-weight, and durable units, the market has emerged quite competitive since the past few years. However, with the onset of the COVID-19 pandemic, the market has witnessed a significant decline due to lockdown measures and economic uncertainties.

In order to help strategic decision-makers, the report also includes competitive profiling of the leading AHU manufacturers, market positioning, and key developments. Some of the major players profiled in the report are GEA Heat Exchangers Group, Wozair Ltd., Mitsubishi Electric, Johnson Controls, Inc., Systemair Ltd., Heinen and Hopman, Flakt Woods Group, Novenco AS and others.

Other in-depth analysis provided in the report includes:

• Current and future market trends to justify the forthcoming attractive markets within the offshore air handling units and HVAC industry
• Market fuelers, market impediments, and their impact on the market growth
• In-depth competitive environment analysis
• Trailing 2-Year market size data (2018 - 2019)
• SRC (Segment-Region-Country) Analysis

Key Topics Covered:

Chapter 1 Preface

Chapter 2 Executive Summary

Chapter 3 Market Dynamics

3.1 Introduction

3.1.1 Global Offshore Air Handling Units Market Revenue and Growth, 2018 - 2028, (US$ Mn) (Y-o-Y %)

3.2 Key Trends and Future Outlook

3.2.1 Product enhancement

3.2.2 Customized products:

3.2.3 Energy saving is the need of the hour:

3.3 Market Drivers

3.3.1 Rising cruise liner industry worldwide

3.3.2 Anticipated growth in oil & gas rigs construction

3.4 Market Growth Inhibitors

3.4.1 Uncertain market conditions and regulations

3.5 Opportunities

3.6 See-Saw Analysis

3.6.1 Impact Analysis of Drivers and Restraints

3.7 Competitive Landscape

3.7.1 Market Positioning of Key Offshore air handling units Manufacturers

Chapter 4 Offshore Air Handling Units Market Analysis, by Application

4.1 Overview

4.2 Packaged Air Handling Units

4.2.1 Global Packaged Offshore Air Handling Units Market Revenue, 2018 - 2028, (US$ Mn)

4.3 Modular Air Handling Units

4.3.1 Global Modular Offshore Air Handling Units Market Revenue, 2018 - 2028, (US$ Mn)

4.4 Custom Air Handling Units

4.4.1 Global Custom Offshore Air Handling Units Market Revenue, 2018 - 2028, (US$ Mn)

Chapter 5 Offshore Air Handling Units Market Analysis, by Fan Type

5.1 Overview

5.2 Single Inlet Single Width (SISW)

5.3 Double Inlet Double Width (DIDW)

Chapter 6 Offshore Air Handling Units Market Analysis, by Capacity

6.1 Overview

6.2 Capacity Less than 5000m3/hr

6.3 Medium Capacity (5000m3/hr to 15000m3/hr)

6.4 High Capacity (more than 15000m3/hr)

Chapter 7 Offshore Air Handling Units Market Analysis, by Application

7.1 Overview

7.2 Oil and Gas Rigs

7.3 Cruise Liners and Yacht

7.4 Defense

7.5 Floating Production Storage and Offloading (FPSO)

7.6 Cargo Ships

7.7 Others

Chapter 8 North America Offshore Air Handling Units Market Analysis

Chapter 9 Europe Offshore Air Handling Units Market Analysis

Chapter 10 Asia Pacific Offshore Air Handling Units Market Analysis

Chapter 11 Middle East & Africa (MEA)Offshore Air Handling Units Market Analysis

Chapter 12 Latin America Offshore Air Handling Units Market Analysis

Chapter 13 Company Profiles

For more information about this report visit https://www.researchandmarkets.com/r/3q7rqq

ResearchAndMarkets.com
Laura Wood, Senior Press Manager
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DALLAS--(BUSINESS WIRE)--Kosmos Energy Ltd. (“Kosmos”) (NYSE: KOS) announced today the pricing of $450 million aggregate principal amount of its 7.500% senior notes due 2028. The offering was upsized by $50 million over the previously announced offering size of $400 million. The offering is expected to close on March 4, 2021, subject to customary closing conditions. Kosmos intends to use the net proceeds from the offering to repay outstanding indebtedness under its revolving credit facility and commercial debt facilities and for general corporate purposes.

The securities offered will not be registered under the Securities Act of 1933, as amended (the “Securities Act”), or any state securities laws and unless so registered, the securities may not be offered or sold in the United States without registration or an applicable exemption from the registration requirements of the Securities Act and applicable state securities or blue sky laws and foreign securities laws. The senior notes and the related guarantees were offered only to persons reasonably believed to be qualified institutional buyers in reliance on the exemption from registration set forth in Rule 144A under the Securities Act, and outside the United States, to non-U.S. persons in reliance on the exemption from registration set forth in Regulation S under the Securities Act.

This press release is being issued pursuant to, and in accordance with, Rule 135c under the Securities Act, and is neither an offer to sell nor a solicitation of an offer to buy the notes or any other securities and shall not constitute an offer to sell or a solicitation of an offer to buy, or a sale of, the notes or any other securities in any jurisdiction in which such offer, solicitation or sale is unlawful.

About Kosmos Energy

Kosmos is a full-cycle deepwater independent oil and gas exploration and production company focused along the Atlantic Margins. Our key assets include production offshore Ghana, Equatorial Guinea and U.S. Gulf of Mexico, as well as a world-class gas development offshore Mauritania and Senegal. Kosmos is listed on The New York Stock Exchange and London Stock Exchange and is traded under the ticker symbol KOS. As an ethical and transparent company, Kosmos is committed to doing things the right way. The Company’s Business Principles articulate our commitment to transparency, ethics, human rights, safety and the environment.

Forward-Looking Statements

This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that Kosmos expects, believes or anticipates will or may occur in the future are forward-looking statements. Kosmos’ estimates and forward-looking statements are mainly based on its current expectations and estimates of future events and trends, which affect or may affect its businesses and operations. Although Kosmos believes that these estimates and forward-looking statements are based upon reasonable assumptions, they are subject to several risks and uncertainties and are made in light of information currently available to Kosmos. When used in this press release, the words “anticipate,” “believe,” “intend,” “expect,” “plan,” “will” or other similar words are intended to identify forward-looking statements. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of Kosmos, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. Further information on such assumptions, risks and uncertainties is available in Kosmos’ Securities and Exchange Commission (“SEC”) filings. Kosmos undertakes no obligation and does not intend to update or correct these forward-looking statements to reflect events or circumstances occurring after the date of this press release, except as required by applicable law. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this press release. All forward-looking statements are qualified in their entirety by this cautionary statement.

European Economic Area and United Kingdom Notices

Financial Conduct Authority (FCA) stabilization rules apply.

MiFIR professionals / ECPs only / No PRIIPs / UK PRIIPs KID - Manufacturer target market (MiFID II product governance) is eligible counterparties and professional clients only (all distribution channels). No PRIIPs regulation key information document (KID) has been prepared as the notes are not available to retail investors in the EEA or the United Kingdom.

Kosmos Energy Ltd.
Investor Relations
Jamie Buckland, +44 (0) 203 954 2831
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or
Media Relations
Thomas Golembeski, +1-214-445-9674
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DUBLIN--(BUSINESS WIRE)--The "Global Floating Power Plant Market - Forecasts from 2021 to 2026" report has been added to ResearchAndMarkets.com's offering.

The global floating power plant market is evaluated at US$1,217.139 Million for the year 2020 growing at a CAGR of 10.03% reaching the market size of US$2,159.766 Million by the year 2026.

Floating power plant refers to the type of power plants that are built on ships or other floating platforms like barges. The concept is comparatively new and several projects are under development owing to the advantages posed by it. The one advantage due to which the concept is gaining a significant amount of traction is that developing a power plant on a ship or a floating platform would help save the operators a substantial amount of space on land.

Additionally, there would be lesser requirement to transport the components of a power plant by road as a floating power plant can be completely be assembled in a shipyard and can be transported on their floating foundations to anywhere using tugboats. A key factor driving the developments in the floating power plant sector is their ability to be transported to a remote coastlands if they have been hit by an earthquake or tsunami with electricity and water where getting either of them gets difficult given the destruction level. Furthermore, a floating power plant can also be use to offset the breakdown of an old power plant. The ease with which they can be moved to another place when their purpose finishes at a place is a key advantage of this concept. The market of floating power plants is expected to witness a significant growth during the forecast period owing to the increasing awareness amongst the operators about the benefits these type of establishments have over the plants that are built on land.

Additionally, with the companies offering various business plans for the operators, it has become easier for the customers to make use of a power plant for various purposes. For instance, Siemens Financial Services have come up with an interesting business model which will allow the customers to buy the floating power plant or if they need they can lend/lease it from them for the duration that they need it. Furthermore, for the cases where the business find the land prices too expensive can opt for the floating version which is expected to be more cost effective comparatively.

A key factor expected to restrict the growth of the market during the forecast period is ability of the floating power plant to tackle rough weather conditions like tsunami and cyclones which might disrupt the working conditions of the plant severely.

The advent of COVID-19 had an adverse impact on the global Floating power plant market since the pandemic brought the activities in power industry to a standstill globally which restricted the research & development activities that are required to be done. After the initial lockdown period, some of the activities were allowed but with restrictions and certain protocols that were required to be followed like the construction and the assembling of the floating power plant will be done with lesser capacity which will require less labour to come in contact and social distancing was required to be maintained in the premises as well. Moreover, the sales of the equipment required for the development of the plant in dipped during the initial months of the year owing to the lockdown which led to the shutting down of the sellers for a certain period initially and thus disrupting the supply chain. Countries across the globe were under lockdown in the year which led to a decline in the prices of several components of a floating power plant globally. With the industries recovering after the pandemic gradually, the ongoing and upcoming developments in the business are expected to operate in full capacity starting from the third and fourth quarters of 2020. This will further help in the recovery of the floating power plant market.

Key Topics Covered:

1. Introduction

2. Research Methodology

3. Executive Summary

4. Market Dynamics

4.1. Market Drivers

4.2. Market Restraints

4.3. Porters Five Forces Analysis

4.4. Industry Value Chain Analysis

5. Floating Power Plant Market Analysis, by Source

5.1. Introduction

5.2. Renewable

5.3. Non-Renewable

6. Floating Power Plant Market Analysis, by Capacity

6.1. Introduction

6.2. 0-50 MW

6.3. 6-20 MW

6.4. 21-100 MW

6.5. 101-250 MW

6.6. above 250 MW

7. Floating Power Plant Market Analysis, by Geography

7.1. Introduction

7.2. North America

7.3. South America

7.4. Europe

7.5. Middle East and Africa

7.6. Asia Pacific

8. Competitive Environment and Analysis

8.1. Major Players and Strategy Analysis

8.2. Emerging Players and Market Lucrativeness

8.3. Mergers, Acquisitions, Agreements, and Collaborations

8.4. Vendor Competitiveness Matrix

9. Company Profiles

9.1. Ciel & Terre international

9.2. Kawasaki Heavy Industries Ltd

9.3. Wartsila Oyj Abp

9.4. Siemens AG

9.5. General Electric Company

9.6. Karadeniz Holding

9.7. Equinor ASA

For more information about this report visit https://www.researchandmarkets.com/r/6wwjj4

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RICHMOND, Va.--(BUSINESS WIRE)--The Board of Directors of NewMarket Corporation (NYSE: NEU) declared a quarterly dividend in the amount of $1.90 per share on the common stock of the Corporation. The dividend is payable April 1, 2021 to NewMarket shareholders of record at the close of business on March 15, 2021.

NewMarket Corporation, through its subsidiaries Afton Chemical Corporation and Ethyl Corporation, develops, manufactures, blends, and delivers chemical additives that enhance the performance of petroleum products. From custom-formulated additive packages to market-general additives, the NewMarket family of companies provides the world with the technology to make engines run smoother, machines last longer, and fuels burn cleaner.

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• CenterPoint Energy reported fourth quarter 2020 earnings of $0.27 per diluted share, $0.29  earnings per diluted share on a guidance basis
• Full-year 2020 results show a loss of $1.79 per diluted share, and $1.40 earnings per diluted share on a guidance basis, with $1.17 from Utility Operations and $0.23 from Midstream Investments 
• Fourth quarter and full-year 2020 guidance basis results beat consensus and guidance 
• Raising 2021 Utility EPS guidance range to $1.24 - $1.26, and reiterating 6% - 8% Utility EPS guidance basis growth rate target and 10% rate base compound annual growth rate 
• CenterPoint Energy remains focused on customers, and is proud of its dedicated employees and the resiliency of its electric and gas systems during the February 2021 winter storm

HOUSTON--(BUSINESS WIRE)--CenterPoint Energy, Inc. (NYSE: CNP) today reported fourth quarter 2020 earnings of $0.27 per diluted common share, compared to $0.25 per diluted common share for the fourth quarter of 2019. On a guidance basis, fourth quarter 2020 earnings were $0.29 per diluted share, compared to $0.35 per diluted share for the fourth quarter of 2019.

CenterPoint Energy also reported a loss available to common shareholders of $949 million, or a loss of $1.79 per diluted share, for the full-year 2020, compared with income available to common shareholders of $674 million, or $1.33 per diluted share for the full-year 2019. Full year 2020 results included after-tax non-cash impairment charges of $1,269 million or $2.25 per diluted share, associated with the company's midstream investments. On a guidance basis, full-year 2020 earnings were $1.40 per diluted share, compared to $1.60 per diluted share for full-year 2019.

“Our service territories, particularly here in Texas, have been significantly impacted by the recent severe winter storm. Our thoughts are with our communities and our customers as they recover from the impacts of this storm,” said Dave Lesar, President and Chief Executive Officer of CenterPoint Energy.

“I am proud of our employees who went above and beyond to manage the impacts of the storm, the generation shortfall, and the resulting ERCOT electricity curtailment. We are also pleased with our system’s performance during this event and proud to report that over 98% of our 2.6 million electric customers had power within 12 hours of having the electricity supply made available to us.”

“We are proactively managing our near-term working capital needs resulting from the February winter storm. Today, we are pleased to announce we have secured $1.7 billion in financing commitments to help us bridge short term liquidity needs. We believe that this short-term financing, along with our existing credit facilities, will help provide ample liquidity for us to address any winter storm-related expenses.”

“Looking back to 2020, our strong guidance based results speak to the quality of our utility business and our ability to withstand headwinds due in part to our exceptional customer growth and timely recovery mechanisms. While maintaining our 6% - 8% guidance basis Utility EPS growth target and 10% rate base compound annual growth rate, we are raising our 2021 guidance basis Utility EPS range to $1.24 - $1.26.”

Lesar added, “We have also recently announced our support of the merger between Enable Midstream Partners, LP and Energy Transfer LP. We committed to taking a disciplined approach to minimizing our midstream exposure on our December 7^th Investor Day and this transaction is a big step for CenterPoint Energy as we deliver on our promises to our shareholders. By taking steps to significantly reduce the risk of our midstream investment and improve the liquidity of the underlying security, we can accelerate our transition to a fully regulated business model. We will keep you updated on the closing of the transaction and our plan to ultimately eliminate our midstream exposure.”

Earnings Outlook

Given the recently announced merger between Enable and Energy Transfer, CenterPoint Energy will only be presenting a guidance basis Utility EPS range for 2021 as Enable did not provide 2021 guidance during its recent earnings call.

In addition to presenting its financial results in accordance with GAAP, including presentation of income (loss) available to common shareholders and diluted earnings (loss) per share, CenterPoint Energy provides guidance based on guidance basis income and guidance basis diluted earnings per share, which are non-GAAP financial measures. Generally, a non-GAAP financial measure is a numerical measure of a company’s historical or future financial performance that excludes or includes amounts that are not normally excluded or included in the most directly comparable GAAP financial measure.

Management evaluates CenterPoint Energy’s financial performance in part based on guidance basis income and guidance basis earnings per share. Management believes that presenting these non-GAAP financial measures enhances an investor’s understanding of CenterPoint Energy’s overall financial performance, by providing them with an additional meaningful and relevant comparison of current and anticipated future results across periods. The adjustments made in these non-GAAP financial measures exclude items that Management believes do not most accurately reflect the company’s fundamental business performance. These excluded items are reflected in the reconciliation tables of this news release, where applicable. CenterPoint Energy’s guidance basis income and guidance basis diluted earnings per share non-GAAP financial measures should be considered as a supplement to, and not as a substitute for, or superior to, income available to common shareholders and diluted earnings per share, which respectively are the most directly comparable GAAP financial measures. These non-GAAP financial measures also may be different than non-GAAP financial measures used by other companies.

(1) Utility EPS Guidance Range

• The Utility EPS guidance range includes net income from Electric and Natural Gas segments, as well as after tax Corporate and Other operating income and an allocation of corporate overhead based upon the Utility’s relative earnings contribution. Corporate overhead consists primarily of interest expense, preferred stock dividend requirements, and other items directly attributable to the parent along with the associated income taxes.
• The Utility EPS guidance excludes:
  • Earnings or losses from the change in value of ZENS and related securities
  • Certain expenses associated with merger integration
  • Midstream Investments segment and associated income from the Enable preferred units and a corresponding amount of debt in addition to an allocation of associated corporate overhead and impact, including related expenses, associated with the merger between Enable and Energy Transfer
  • Cost associated with the early extinguishment of debt
  • Gain and impact, including related expenses, associated with gas LDC sales

In providing this guidance, CenterPoint Energy does not consider the items noted above and other potential impacts such as changes in accounting standards, impairments or other unusual items, which could have a material impact on GAAP reported results for the applicable guidance period. The 2021 Utility EPS guidance range also considers assumptions for certain significant variables that may impact earnings, such as customer growth and usage including normal weather, throughput, recovery of capital invested, effective tax rates, financing activities and related interest rates, and regulatory and judicial proceedings. In addition, the 2021 Utility EPS guidance range assumes a continued re-opening of the economy in CenterPoint Energy’s service territories throughout 2021. To the extent actual results deviate from these assumptions, the 2021 Utility EPS guidance range may not be met or the projected annual Utility EPS growth rate may change. CenterPoint Energy is unable to present a quantitative reconciliation of forward-looking guidance basis diluted earnings per share because changes in the value of ZENS and related securities, future impairments, and other unusual items are not estimable and are difficult to predict due to various factors outside of management’s control.

(2) Midstream Investments EPS Expected Range

Midstream guidance is not initiated at this time as a result of a pending merger between Enable and Energy Transfer. CenterPoint Energy will continue to record its share of Enable’s earnings as well as basis difference accretion, earnings from the Enable preferred distributions net of an associated amount of debt, interest on the Midstream note, and an allocation of corporate overhead based on Midstream Investment segment’s relative earnings contribution until the transaction closes.

Upon closing of the transaction, CenterPoint Energy’s investment in Energy Transfer will be accounted for as an equity method investment with a fair value option. Following the closing of the transaction, CenterPoint Energy will establish Midstream Investments EPS expected range based on the distributions from Energy Transfer and the debt and corporate allocations previously described as a component of our Midstream Investments, excluding market-to-market gains or losses recorded for the Energy Transfer investments.

Reconciliation of Consolidated income (loss) available to common shareholders and diluted earnings (loss) per share (GAAP) to guidance basis income and guidance basis diluted earnings per share (Non-GAAP)