Search the web
Welcome, Guest
[Sign Out, My Account]
EDGAR_Online

Quotes & Info
Enter Symbol(s):
e.g. YHOO, ^DJI
Symbol Lookup | Financial Search
ROYT > SEC Filings for ROYT > Form 10-Q on 12-May-2014All Recent SEC Filings

Show all filings for PACIFIC COAST OIL TRUST

Form 10-Q for PACIFIC COAST OIL TRUST


12-May-2014

Quarterly Report


Item 2. Trustee's Discussion and Analysis of Financial Condition and Results
of Operations.

The following review of the Trust's financial condition and results of operations should be read in conjunction with the financial statements and notes thereto, as well as Trustee's Discussion and Analysis of Financial Condition and Results of Operations contained in the Trust's 2013 Annual Report on Form 10-K, as amended. The following review should also be read in conjunction with the "Cautionary Statement Regarding Forward-Looking Information" in this report and Part I - Item 1A - "Risk Factors" in the Trust's Annual Report on Form 10-K, as amended.

Overview

The Trust is a statutory trust formed in January 2012 under the Delaware Statutory Trust Act. The business and affairs of the Trust are administered by the Trustee. The Trust's purpose is to hold the Conveyed Interests (described below), to distribute to the Trust unitholders cash that the Trust receives in respect of the Conveyed Interests, subject to the effects of the commodity derivative contracts described in Note 4 to the financial statements contained in Part I, Item 1 of this Quarterly Report, and to perform certain administrative functions in respect of the Conveyed Interests and the Trust units. The Trust does not conduct any operations or activities. The Trustee has no authority over or responsibility for, and no involvement with, any aspect of the oil and gas operations or other activities on the Underlying Properties. Wilmington Trust, National Association, as the Delaware Trustee (the "Delaware Trustee"), has only minimal rights and duties as are necessary to satisfy the requirements of the Delaware Statutory Trust Act. The Trust derives all or substantially all of its income and cash flow from the Conveyed Interests, subject to the effects of the commodity derivative contracts. The Trust is treated as a grantor trust for U.S. federal income tax purposes.

The Trust was created to acquire and hold net profits and royalty interests in certain oil and natural gas properties located in California. The Conveyed Interests (as defined below) represent undivided interests in underlying properties consisting of PCEC's interests in its oil and natural gas properties located onshore in California (the "Underlying Properties"). The Conveyed Interests were conveyed by PCEC to the Trust concurrent with the initial public offering of the Trust's common units in May 2012.

Concurrent with the initial public offering, on May 8, 2012, the Trust and PCEC entered into a Conveyance of Net Profits Interests and Overriding Royalty Interest (the "Conveyance"), pursuant to which PCEC conveyed to the Trust net profits interest and an overriding royalty interest (the "Conveyed Interests") in certain oil and natural gas properties in California (the "Underlying Properties"). The Conveyed Interests entitle the Trust to receive 80% of the net profits from the sale of oil and natural gas production from the proved developed reserves as of December 31, 2011 on the Underlying Properties (the "Developed Properties") and either 25% of the net profits from the sale of oil and natural gas production from all other development potential on the Underlying Properties (the "Remaining Properties") or a 7.5% royalty interest from the sale of oil and natural gas production from the Remaining Properties located in PCEC's Orcutt properties (the "Royalty Interest Proceeds").

The Trust calculates the net profits and royalties for the Developed Properties and Remaining Properties monthly. For any monthly period during which costs for the Remaining Properties exceed gross proceeds, the Trust is entitled to receive the Royalty Interest Proceeds, and the Trust would continue to receive such proceeds until the first day of the month following the day on which cumulative gross proceeds for the Remaining Properties exceed the cumulative total excess costs for the Remaining Properties (such occurrence being herein called an "NPI Payout"). Due to significant planned capital expenditures associated with the Remaining Properties for the benefit of the Trust, PCEC expects the Trust to receive payments associated with the Remaining Properties in the form of Royalty Interest Proceeds until the NPI Payout occurs in approximately 2020. In any monthly period following an NPI Payout, the Trust is entitled to receive Royalty Interest Proceeds if costs for the Remaining Properties exceed gross proceeds.

The Trust will make monthly cash distributions of all of its monthly cash receipts, after deduction of fees and expenses for the administration of the Trust, to holders of its Trust units as of the applicable record date (generally within five business days after the last business day of each calendar month). Distributions are payable on or before the 10th business day after the record date. Actual cash distributions to the Trust unitholders will fluctuate monthly based upon the quantity of oil and natural gas produced from the Underlying Properties, the prices received for oil and natural gas production, costs to develop and produce the oil and natural gas and other factors. Because payments to the Trust will be generated by depleting assets with the production from the Underlying Properties diminishing over time, a portion of each distribution will represent, in effect, a return of a unitholder's original investment. Oil and natural gas production from proved reserves attributable to the Underlying Properties will decline over time.

2014 Capital Program Summary

PCEC has informed the Trustee that its calendar year 2014 capital program is expected to total approximately $21.7 million. This total includes expected investments of approximately $8.8 million ($7.1 million net to the Trust's interest) in the Developed Properties. Approximately $12.8 million is expected to be spent on the Remaining Properties, which will not affect distributions in the current period, but the Trust's 25% pro rata share of $3.2 million may affect the date on which the NPI Payout occurs.


Table of Contents

Properties

The Underlying Properties consist of (i) the proved developed reserves as of December 31, 2011 on the Underlying Properties (the "Developed Properties,") and
(ii) all other development potential on the Underlying Properties (the "Remaining Properties"). Production from the Developed Properties that will be attributable to the Trust is produced from wells that, because they have already been drilled, require limited additional capital expenditures. Production from the Remaining Properties that will be attributable to the Trust will require capital expenditures for the drilling of wells and installation of infrastructure. PCEC will supply required capital on behalf of the Trust during this period; however, because the costs initially incurred will exceed gross proceeds, the Remaining Properties will have negative net profits during the drilling and development period. During this period of negative net profits, instead of being paid net profits, the Trust will be paid a 7.5% overriding royalty on the portion of the Remaining Properties located on PCEC's Orcutt properties. Once revenues from the Remaining Properties have paid back PCEC for the cumulative costs it has advanced on behalf of the Trust, the net profits interests on the Remaining Properties will be paid out in place of the royalty interests, as described below. The net profits interests and royalty interest conveyed to the Trust are referred to herein as the "Net Profits Interests" and "Royalty Interest," respectively. These interests, collectively the "Conveyed Interests," entitle the Trust to receive the following:

Developed Properties

80% of the net profits from the sale of oil and natural gas production from the Developed Properties.

Remaining Properties

7.5% of the proceeds (free of any production or development costs but bearing the proportionate share of production and property taxes and post-production costs) attributable to the sale of all oil and natural gas production from the Remaining Properties located on PCEC's Orcutt properties, including but not limited to PCEC's interest in such production (the "Royalty Interest Proceeds"), or

25% of the net profits from the sale of oil and natural gas production from all of the Remaining Properties.

The Trust calculates the net profits and royalties for the Developed Properties and the Remaining Properties separately. Any excess costs for either the Developed Properties or the Remaining Properties will not reduce net profits calculated for the other. The amount of Royalty Interest Proceeds paid will be taken into account in the net profits interest calculation for the Remaining Properties. If at any time cumulative costs for the Developed Properties or the Remaining Properties exceed cumulative gross proceeds associated with such properties, neither the Trust nor the Trust unitholders would be liable for the excess costs, but the Trust would not receive any net profits from the Developed Properties or the Remaining Properties, as the case may be, until future cumulative net profits for such properties exceed the cumulative total excess costs for such properties.

The Trust is not subject to any pre-set termination provisions based on a maximum volume of oil or natural gas to be produced or the passage of time. The Trust will dissolve upon the earliest to occur of the following: (1) the Trust, upon approval of the holders of at least 75% of the outstanding Trust units, sells the Net Profits Interest, (2) the annual cash available for distribution to the Trust is less than $2 million for each of any two consecutive years,
(3) the holders of at least 75% of the outstanding Trust units vote in favor of dissolution or (4) the Trust is judicially dissolved.

Commodity Derivative Contracts

The revenues derived from the Underlying Properties depend substantially on prevailing oil prices and, to a lesser extent, natural gas prices. As a result, commodity prices also affect the amount of cash flow available for distribution to the Trust unitholders. Lower prices may also reduce the amount of oil and natural gas that PCEC or the third-party operators can economically produce. PCEC has entered into commodity derivative contracts to reduce the exposure of the revenues from oil production from the Underlying Properties to fluctuations in oil prices and to achieve more predictable cash flow. However, these contracts limit the amount of cash available for distribution if prices increase above the fixed contract price. None of the Trust's exposure to natural gas prices is hedged.

PCEC had commodity derivative contracts with Wells Fargo Bank, National Association in order to mitigate the effects of falling commodity prices through March 31, 2014. The Trust was entitled to the effect of 2,000 barrels of daily swap volumes of Brent crude oil at $115.00 per barrel during the twenty-four months ended March 31, 2014, proportional to the Trust's interest in the Developed Properties.


Table of Contents

The amounts received by PCEC from the commodity derivative contract counterparty upon settlement of the commodity derivative contracts reduced or increased the operating expenses related to the Underlying Properties in calculating net profits.

Results of Operations for the Three Months Ended March 31, 2014 and 2013

For the three months ended March 31, 2014, income from Conveyed Interests received by the Trust amounted to $15.2 million compared with $17.5 million for the three months ended March 31, 2013. The net profits income received by the Trust during the three months ended March 31, 2014 was primarily associated with net profits for oil and natural gas production during the months of November and December 2013 and January 2014. The net profits income received by the Trust during the three months ended March 31, 2013 was primarily associated with net profits for oil and natural gas production during the months of November and December 2012 and January 2013.

The following table displays PCEC's underlying sales volumes and average prices for the Underlying Properties, representing the amounts included in the net profits calculation for distributions paid during the three months ended March 31, 2014 and 2013.

                                       Three Months Ended
                                           March 31,
                                        2014         2013
Developed Properties:
Underlying sales volumes (Boe) (a)      330,856     331,712
Average daily production (Boe/d)          3,676       3,686
Average price (per Boe)              $    91.98    $  97.95
Production cost (per Boe)            $    33.67    $  33.29

Remaining Properties:
Underlying sales volumes (Boe) (b)       74,553      68,778
Average daily production (Boe/d)            828         764
Average price (per Boe)              $    91.67    $  97.49
Production cost (per Boe)            $    20.01    $  17.57



(a) Crude oil sales represented 97% of total sales volumes from the Developed Properties for each of the three months ended March 31, 2014 and 2013.

(b) Crude oil sales represented 100% of total sales volumes from the Remaining Properties for each of the three months ended March 31, 2014 and 2013.


Table of Contents

Computation of Net Profits and Royalty Income Received by the Trust

The Trust's net profits and royalty income consist of monthly net profits and royalty income attributable to the Conveyed Interests. Net profits and royalty income for the three months ended March 31, 2014 and 2013 were determined as shown in the following table.

                                                    Three Months Ended      Three Months Ended
Thousands of dollars                                  March 31, 2014          March 31, 2013
Developed Properties-80% Net Profits Interest
Gross profits:
Oil sales                                          $             30,184    $             32,225
Natural gas sales                                                   249                     267
Total                                                            30,433                  32,492
Costs:
Direct operating expenses:
Lease operating expenses                                         10,260                   9,982
Production and other taxes                                          880                   1,062
Development expenses                                              2,139                   1,025
Total                                                            13,279                  12,069
Total income                                                     17,154                  20,423
Net Profits Interest                                                 80 %                    80 %
Income from Net Profits Interest                   $             13,723    $             16,339
Remaining Properties-25% Net Profits Interest
Total Revenues:
Oil sales                                          $              6,835    $              6,705
Total                                                             6,835                   6,705
7.5% Overriding Royalty Interest                                    494                     503
Costs:
Direct operating expenses:
Lease operating expenses                                          1,282                   1,136
Production and other taxes                                          211                      72
Development expenses                                              3,427                   5,071
Total                                                             4,920                   6,279
Total income (excess cost)                                        1,421                     (77 )
Net Profits Interest                                                 25 %                    25 %
25% Net Profits Interest Income (Deficit)(1)       $                355    $                (19 )
Total Trust Cash Flow
80% net profit interest                            $             13,723    $             16,339

7.5% overriding royalty interest                                    494                     503
Settlement of commodity derivative contracts                      1,189                     867
PCEC operating and service fee                                     (255 )                  (250 )
Total                                              $             15,151    $             17,459
Trust general and administrative expenses and
cash withheld for expenses                                         (180 )                  (305 )
Distributable income                               $             14,971    $             17,154




--------------------------------------------------------------------------------
                                                Three Months Ended     Three Months Ended
(1) 25% Net Profits Interest Accrued Deficit      March 31, 2014         March 31, 2013
Beginning balance                              $             (3,591 ) $             (5,223 )
Current period                                                  355                    (19 )
Ending balance                                 $             (3,236 ) $             (5,242 )

Three months ended March 31, 2014 and 2013

Developed Properties - Income from the Developed Properties, before net settlements related to commodity derivative contracts, was approximately $13.7 million for the three months ended March 31, 2014 compared to $16.3 million for the three months ended March 31, 2013. The decrease is attributable principally to lower oil prices, higher sale price differentials and lower production compared to the prior year quarter; in addition, higher development related capital expenditures contributed to the decrease in income. Total capital expenditures included in the net profits calculation during the quarter were approximately $2.1 million for the three months ended March 31, 2014 compared to $1.0 million for the three months ended March 31, 2013. Total lease operating expenses included in the net profits calculation during the quarter were approximately $10.3 million for the three months ended March 31, 2014 compared to $10.0


Table of Contents

million for the three months ended March 31, 2013. Production and other taxes were approximately $0.9 million for the three months ended March 31, 2014 compared to $1.1 million for the three months ended March 31, 2013. Net settlements related to commodity derivative contracts were $1.2 million for the three months ended March 31, 2014 compared to $0.9 million for the three months ended March 31, 2013.

Remaining Properties - For the Remaining Properties, NPI income was $0.4 million for the three months ended March 31, 2014 compared to a deficit of $19,000 for the three months ended March 31, 2013. Since a cumulative deficit existed on the 25% net profits interest, the Trust received approximately $0.5 million during each of the three months ended March 31, 2014 and 2013 from the 7.5% Overriding Royalty attributable to the sale of all production from the Remaining Properties located on PCEC's Orcutt Properties. The cumulative deficit of the net profits interest on the Remaining Properties, including payments to the Trust pursuant to the 7.5% Overriding Royalty, was approximately $3.2 million at March 31, 2014 compared to $5.2 million at March 31, 2013.

PCEC charged the Trust $0.3 million and $0.3 million for the Operating and Service Fee for the three months ended March 31, 2014 and March 31, 2013, respectively. The annual amount of the Operating and Service Fee was $1.0 million from April 1, 2012 through March 31, 2013. Commencing April 1, 2013, the Operating and Services Fee increased 2% to $1,021,000 based on changes to the CPI. The fee will adjust annually each April 1, and commencing April 1, 2014 it increased 1.5% to $1,035,955.

The total cash received by the Trust from PCEC for the three months ended March 31, 2014 and 2013 was approximately $15.2 million and $17.5 million, respectively. The Trustee paid general and administrative expenses of $0.2 million and $0.3 million during the first quarter of 2014 and 2013, respectively. Expenses paid during the first quarter of 2014 primarily consisted of Trustee fees, accounting fees and legal fees. Expenses paid during the first quarter of 2013 primarily consisted of Trustee fees, accounting fees and New York Stock Exchange listing fees. The distributable income was approximately $15.0 million for the quarter ended March 31, 2014 compared to $17.2 million for the quarter ended March 31, 2013.

Liquidity and Capital Resources

Other than Trust administrative expenses, including payment of the PCEC operating and services fee and any reserves established by the Trustee for future liabilities, the Trust's only use of cash is for distributions to Trust unitholders. Available funds are the excess cash, if any, received by the Trust from the Conveyed Interests and other sources (such as interest earned on any amounts reserved by the Trustee) in that month, over the Trust's expenses paid for that month. Available funds are reduced by any cash the Trustee determines to hold as a reserve against future expenses.

The Trustee may create a cash reserve to pay for future liabilities of the Trust. If the Trustee determines that the cash on hand and the cash to be received are, or will be, insufficient to cover the Trust's liabilities, the Trustee may cause the Trust to borrow funds to pay liabilities of the Trust. The Trustee may also cause the Trust to mortgage its assets to secure payment of the indebtedness. If the Trustee causes the Trust to borrow funds, the Trust unitholders will not receive distributions until the borrowed funds are repaid.

Each month, the Trustee pays Trust obligations and expenses and distributes to the Trust unitholders the remaining proceeds received from the Conveyed Interests. The cash held by the Trustee as a reserve against future liabilities or for distribution at the next distribution date may be invested in a limited number of permitted investments. Alternatively, cash held for distribution at the next distribution date may be held in a noninterest bearing account.

PCEC has provided the Trust with a $1.0 million letter of credit to be used by the Trust in the event that its cash on hand (including available cash reserves) is not sufficient to pay ordinary course administrative expenses as they become due. Further, if the Trust requires more than the $1.0 million under the letter of credit to pay administrative expenses, PCEC has agreed to loan funds to the Trust necessary to pay such expenses. Any funds provided under the letter of credit or loaned by PCEC may only be used for the payment of 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, and may not be used to satisfy Trust indebtedness. If the Trust draws on the letter of credit or PCEC loans funds to the Trust, no further distributions will be made to Trust unitholders (except in respect of any previously determined monthly cash distribution amount) until such amounts drawn or borrowed, including interest thereon, are repaid. Any loan made by PCEC will be on an unsecured basis, and the terms of such loan will be substantially the same as those which would be obtained in an arm's-length transaction between PCEC and an unaffiliated third party.

The Trustee has no current plans to authorize the Trust to borrow money. During the quarter ended March 31, 2014, there were no borrowings.


Table of Contents

Distributions Paid and Declared After Quarter End

On April 14, 2014, the distribution of $0.12188 per Trust Unit, which was declared on March 24, 2014, was paid to Trust unitholders owning Trust Units as of April 3, 2014.

On April 24, 2014 the Trust declared a distribution of $0.12102 per unit to unitholders of record as of May 7, 2014. The distribution is payable to Trust unitholders on May 14, 2014.

Off-Balance Sheet Arrangements

The Trust has no off-balance sheet arrangements and does not have any transactions, arrangements or other relationships with unconsolidated entities or persons that could materially affect the Trust's liquidity or the availability of capital resources.

New Accounting Pronouncements

As the Trust's financial statements are prepared on the modified cash basis, most accounting pronouncements are not applicable to the Trust's financial statements. No new accounting pronouncements have been adopted or issued that would impact the financial statements of the Trust.

Critical Accounting Policies and Estimates

Please read "Item 7. Trust's Discussion and Analysis of Financial Condition and Results of Operations-Critical Accounting Policies and Estimates" of the Trust's 2013 Annual Report on Form 10-K, as amended, for additional information regarding the Trust's critical accounting policies and estimates. There were no material changes to the Trust's critical accounting policies or estimates during the quarter ended March 31, 2014.

  Add ROYT to Portfolio     Set Alert         Email to a Friend  
Get SEC Filings for Another Symbol: Symbol Lookup
Quotes & Info for ROYT - All Recent SEC Filings
Copyright © 2014 Yahoo! Inc. All rights reserved. Privacy Policy - Terms of Service
SEC Filing data and information provided by EDGAR Online, Inc. (1-800-416-6651). All information provided "as is" for informational purposes only, not intended for trading purposes or advice. Neither Yahoo! nor any of independent providers is liable for any informational errors, incompleteness, or delays, or for any actions taken in reliance on information contained herein. By accessing the Yahoo! site, you agree not to redistribute the information found therein.