0001185185-21-000701.txt : 20210521 0001185185-21-000701.hdr.sgml : 20210521 20210521105016 ACCESSION NUMBER: 0001185185-21-000701 CONFORMED SUBMISSION TYPE: 8-K PUBLIC DOCUMENT COUNT: 13 CONFORMED PERIOD OF REPORT: 20210521 ITEM INFORMATION: Other Events FILED AS OF DATE: 20210521 DATE AS OF CHANGE: 20210521 FILER: COMPANY DATA: COMPANY CONFORMED NAME: Energy 11, L.P. CENTRAL INDEX KEY: 0001581552 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 463070515 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 8-K SEC ACT: 1934 Act SEC FILE NUMBER: 000-55615 FILM NUMBER: 21947277 BUSINESS ADDRESS: STREET 1: 814 EAST MAIN STREET CITY: RICHMOND STATE: VA ZIP: 23219 BUSINESS PHONE: 804-344-8121 MAIL ADDRESS: STREET 1: 814 EAST MAIN STREET CITY: RICHMOND STATE: VA ZIP: 23219 FORMER COMPANY: FORMER CONFORMED NAME: American Energy XI, L.P. DATE OF NAME CHANGE: 20130715 8-K 1 energy1120210520_8k.htm FORM 8-K energy1120210520_8k.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549 

 

 

FORM 8-K

 

 

CURRENT REPORT

 

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

 

Date of Report (Date of earliest event reported): May 21, 2021

 

ENERGY 11, L.P.

(Exact name of registrant as specified in its charter)

 

Delaware

000-55615

46-3070515

(State or other jurisdiction of

(Commission File Number)

(IRS Employer

incorporation)

  

Identification No.)

 

120 W 3rd Street, Suite 220

Fort Worth, Texas

  

76102

(Address of principal executive offices)

  

(Zip Code)

 

Registrant’s telephone number, including area code: (817) 882-9192

 

                        Not Applicable                             

(Former name or former address, if changed since last report)

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

 

☐

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

 

☐

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

 

☐

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

 

☐

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 

Securities registered pursuant to Section 12(b) of the Act:

 

Title of each class

Trading Symbol

Name of each exchange on which registered

None

    

 

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (17 CFR §230.405) or Rule 12b-2 of the Securities Exchange Act of 1934 (17 CFR §240.12b-2).

Emerging growth company ☐

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐ 

 

 
 

 

Energy 11, L.P. (the “Partnership”) is filing this report in accordance with Item 8.01 of Form 8-K.

 

Item 8.01.  Other Events

 

On May 13, 2021, the Partnership entered into a new $60 million revolving credit facility that matures on March 1, 2024. The Partnership was required to update its reserves from December 31, 2020 in conjunction with performing the due diligence for securing the new debt facility. Therefore, the Partnership is providing an estimated per common unit value of the Partnership’s common units as of March 31, 2021 of $10.09 per common unit, as further described below. This estimated per common unit value of the Partnership’s common units as of March 31, 2021 also can assist trustees and custodians of individual retirement accounts (“IRAs”) containing an investment in the Partnership’s common units and to assist broker-dealers in meeting their customer account statement reporting obligations under Financial Industry Regulatory Authority (“FINRA”) rules for investments in the Partnership. There can be no assurance that this estimated value per common unit, or the method used to estimate such value, complies with requirements applicable to a trustee’s, custodian’s or broker-dealer’s obligations with respect to IRAs or FINRA’s reporting requirements. At March 31, 2021, the Partnership owns an approximate 25% non-operated working interest in 243 producing wells, an estimated approximate 17% non-operated working interest in 24 wells in various stages of the drilling and completion process and future possible development sites in the Sanish field located in Mountrail County, North Dakota. The average age of the Partnership’s producing wells is approximately 8 years.

 

Methodology

 

The fair value estimate of the Partnership’s common units was based upon a third-party valuation, performed by Pinnacle Energy Services of Oklahoma City, Oklahoma, of the Partnership’s oil and natural gas properties and management’s estimate of the fair value of the Partnership’s other assets and liabilities as of March 31, 2021. The developed per common unit value range is $8.75 – $11.66. The Partnership utilized the mid-point of the assumptions discussed below to determine the estimated value per common unit above. The following is a summary of the details of the fair value estimate:

 

(in thousands, except per common unit data)

  

Estimate at 03/31/21

  
   

(unaudited)

  
         

Estimated fair value of oil and gas properties

   $ 226,693  

Estimated fair value of cash and cash equivalents

     1,298  

Estimated fair value of other assets and liabilities, net

     3,376  

Estimated fair value of outstanding debt

     (40,000

)

Estimated fair value of equity

   $ 191,367  
         

Common units outstanding

     18,973  
         

Estimated value per common unit

   $ 10.09  

 

Since the Partnership’s common units are not listed on a national securities exchange, no material public market exists for the Partnership’s common units. As a result, although not prepared for generally accepted accounting purposes, the value estimate of the Partnership’s oil and gas properties was derived from unobservable inputs and was based on the income approach as outlined in Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 820, Fair Value Measurements and Disclosures. In the income approach, the estimated value of the Partnership’s oil and gas properties was calculated from a discounted cash flow model using consolidated projected cash flows of the Partnership’s reserves, as well as a discount rate based on market conditions at March 31, 2021. An additional market-based adjustment was made to reflect the probability of successful future development of the Partnership’s oil and gas reserves at March 31, 2021. The Partnership’s cash and cash equivalents are all highly liquid with maturities of three months or less and the fair market value approximates the carrying value. The Partnership’s other assets and liabilities include receivables from the sale of oil, natural gas and natural gas liquids, accounts payable and accrued expenses, which are short-term in nature, and the carrying value of these assets and liabilities approximates fair value at March 31, 2021. The carrying value of the Partnership’s outstanding debt was considered to approximate fair value at March 31, 2021 based on general market conditions and its maturity. The valuation methodology and calculations were reviewed by management of the Partnership and considered reasonable. The estimated value was not based on an appraisal of the Partnership’s assets. 

 

 
 

 

Limitations of the Estimated Value per Common Unit

 

As with any methodology used to estimate value, the methodology employed by the Partnership was based upon a number of estimates and assumptions that may not be accurate or complete and may not accurately reflect future conditions. The estimates and assumptions underlying the estimated value involve judgments with respect to, among other things, future economic, competitive, regulatory and financial market conditions and future business decisions which may not be realized and that are inherently subject to significant business, economic, competitive and regulatory uncertainties and contingencies, including, among others, risks and uncertainties described in the periodic reports filed by the Partnership with the Securities and Exchange Commission (“SEC”), all of which are difficult to predict and many of which are beyond the control of the Partnership. Further, different parties using different assumptions and estimates could derive a different estimated value per common unit, which could be significantly different from the Partnership’s estimated value per common unit.

 

The estimated per common unit value does not represent: (i) the amount at which the Partnership’s common units would trade on a national securities exchange, (ii) the amount a limited partner would obtain if he or she tried to sell his or her common units or (iii) the amount limited partners would receive if the Partnership liquidated its assets and distributed the proceeds after paying all expenses and liabilities. Accordingly, with respect to the estimated value per common unit, the Partnership can give no assurance that:

 

 

•

a limited partner would be able to resell his or her common units at this estimated value;
 

•

a limited partner would ultimately realize distributions per common unit equal to the estimated value per common unit upon liquidation of the Partnership’s assets and settlement of its liabilities or a sale of the Partnership (in part because estimated values do not necessarily indicate the price at which individual assets or the Partnership could be sold, oil and gas property values fluctuate and change, and the estimated value may not take into account the expenses associated with such a sale);
 

•

the Partnership’s common units would trade at a price equal to or greater than the estimated value per common unit if they were listed on a national securities exchange;
 

•

the methodology used to estimate the value per common unit would be acceptable to FINRA or for compliance with requirements applicable to a trustee’s or custodian’s obligations with respect to IRAs; or
 

•

any or all of the assumptions used in estimating the value per common unit will prove to be accurate or complete.

 

The estimated value reflects the fact that the estimate was calculated as of a point in time. The value of the Partnership’s common units will likely change over time and will be influenced by changes to the value of individual assets, changes in the oil and gas industry, as well as changes and developments in the energy and capital markets. The Partnership does not intend to update or otherwise revise the above information to reflect circumstances existing after the date when made or to reflect the occurrence of future events, even in the event that any or all of the assumptions underlying the information are no longer appropriate.

 

Assumptions Used in Estimated Value per Common Unit

 

As discussed above, the estimated value of the Partnership’s oil and gas properties was determined based on various market level assumptions, including but not limited to commodity market prices, discount rates and processing and transportation costs. The following is a list of key assumptions used in the calculation of the estimated value of the Partnership’s oil and gas properties, a component of the estimated value per common unit:

 

 

•

NYMEX oil strip pricing as of April 1, 2021, which ranges from $58.35 per barrel to $48.86 per barrel as of April 1, 2021 to December 31, 2025, and an increase of 3% thereafter with price cap at $85.00 per barrel
 

•

NYMEX gas strip pricing as of April 1, 2021, which ranges from $2.76 per Mcf to $2.59 per Mcf as of April 1, 2021 to December 31, 2025, and an increase of 3% thereafter with price cap of $4.50 per Mcf
 

•

Differentials to NYMEX strip pricing due to product processing, transportation or contract terms
 

o

Weighted average oil differential of $7.49 per barrel of oil
 

o

Weighted average natural gas differential of $2.54 per Mcf of natural gas
 

o

Natural gas liquids (NGL) pricing determined using 14.0% of NYMEX oil price
 

o

Weighted average natural gas shrink of 30.2%
 

o

NGL yield of 109.57 barrels per MMcf of wet gas
 

•

Discount rate – 10.0%

 

 

 
 

 

 

•

Risk adjustments to calculated present value
 

o

Proved developed producing (PDP) assets – 5.0%
 

o

Proved developed non-producing (PDNP) assets – 10.0%
 

o

Proved undeveloped (PUD) assets to be drilled within five years – 15.0%
 

o

Proved undeveloped (PROB) assets to be drilled between five and ten years – 25.0%
 

o

Proved undeveloped (POSS) assets to be drilled after ten years – 35.0%
 

•

Total lease operating and workover expenses per well estimated at $8.50 per barrel of oil
 

•

Gross capital expenditures to drill and complete future development locations estimated at $7.4 million per well

 

A change in any of the assumptions would likely produce a different estimated value per common unit. For example:

 

 

•

An increase in the discount rate assumption of 100 basis points would decrease the per common unit value range by approximately $1.31 per common unit, all other assumptions remaining the same;
 

•

A decrease in the discount rate assumption of 100 basis points would increase the per common unit value range by approximately $1.57 per common unit, all other assumptions remaining the same;
 

•

An increase in the average NYMEX oil and natural gas strip pricing assumptions of 500 basis points would increase the per common unit value range by approximately $1.24 per common unit, all other assumptions remaining the same;
 

•

A decrease in the average NYMEX oil and natural gas strip pricing assumptions of 500 basis points would decrease the per common unit value range by approximately $1.34 per common unit, all other assumptions remaining the same;
 

•

An increase of 500 basis points in the risk adjustment percentage to calculated present value per reserve category would decrease the per common unit value range by approximately $0.71 per common unit, all other assumptions remaining the same; and
 

•

A decrease of 500 basis points in the risk adjustment percentage to calculated present value per reserve category would increase the per common unit value range by approximately $0.70 per common unit, all other assumptions remaining the same.

 

 
 

 

Forward-Looking Statements

 

Certain statements contained in this Current Report on Form 8-K other than historical facts may be considered forward-looking statements. These forward-looking statements are predictions and generally can be identified by use of statements that include phrases such as “may,” “believe,” “expect,” “anticipate,” “intend,” “estimate,” “project,” “target,” “goal,” “plan,” “should,” “will,” “predict,” “potential,” and similar expressions that convey the uncertainty of future events or outcomes. Such statements involve known and unknown risks, uncertainties, and other factors which may cause the actual results, performance, or achievements of the Partnership to be materially different from future results, performance or achievements expressed or implied by such forward-looking statements. Such factors include, but are not limited to, the ability of the Partnership to implement its operating strategy; the ability of the Partnership to manage planned growth; the ability of the Partnership to provide liquidity opportunities for its limited partners; changes in general political, economic and competitive conditions and specific market conditions; adverse changes in the energy and capital markets; financing risks; litigation; regulatory proceedings or inquiries; and changes in laws or regulations or interpretations of current laws and regulations that impact the Partnership’s business. Although the Partnership believes that the assumptions underlying the forward-looking statements contained herein are reasonable, any of the assumptions could be inaccurate, and therefore there can be no assurance that such statements included in this Current Report on Form 8-K will prove to be accurate. In light of the significant uncertainties inherent in the forward-looking statements included herein, the inclusion of such information should not be regarded as a representation by the Partnership or any other person that the results or conditions described in such statements or the objectives and plans of the Partnership will be achieved. Readers should carefully review the Partnership’s financial statements and the notes thereto, as well as the risk factors described in the Partnership’s filings with the SEC, including, but not limited to, in the section entitled “Item 1A. Risk Factors” in the Annual Report on Form 10-K filed by the Partnership with the SEC on March 12, 2021. Any forward-looking statement that the Partnership makes speaks only as of the date of this Current Report on Form 8-K. The Partnership undertakes no obligation to publicly update or revise any forward-looking statements or cautionary factors, as a result of new information, future events, or otherwise, except as required by law.

 

 

 

 
 

 

SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

Date:

May 21, 2021

    
       
   

ENERGY 11, L.P.
       
   

By:

/s/ David McKenney 
     

David McKenney
     

Chief Financial Officer of Energy 11 GP, LLC

 

 

 
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