Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the Securities Exchange
Act of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days.
Yes
[
X
] No [ ]
Indicate by check mark whether the registrant has submitted
electronically and posted on its corporate Web site, if any, every Interactive
Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this
chapter) during the preceding 12 months (or for such shorter period that the
registrant was required to submit and post such files).
Yes
[
X
] No [ ]
Indicate by check mark whether the registrant is a large
accelerated filer, an accelerated filer, a non-accelerated filer, smaller
reporting company, or an emerging growth company. See the definitions of large
accelerated filer, accelerated filer, smaller reporting company, and
emerging growth company in Rule 12b-2 of the Exchange Act.:
If an emerging growth company, indicate by check mark if the
registrant has elected not to use the extended transition period for complying
with any new or revised financial accounting standards provided pursuant to
Section 13(a) of the Exchange Act. [ ]
Indicate by check mark whether the registrant is a shell
company (as defined in Rule 12b-2 of the Exchange Act).
Yes [
] No [
X
]
Indicate the number of shares outstanding of each of the
issuers classes of common stock, as of the latest practicable date.
PART I FINANCIAL INFORMATION
Item 1 Consolidated Financial Statements
U.S. GEOTHERMAL INC.
CONSOLIDATED BALANCE SHEETS
|
|
(Unaudited)
|
|
|
|
|
|
|
March 31,
|
|
|
December 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
|
|
|
|
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current:
|
|
|
|
|
|
|
Cash and cash equivalents
|
$
|
13,068,978
|
|
$
|
15,287,144
|
|
Restricted cash and
security bonds
|
|
9,815,136
|
|
|
8,527,462
|
|
Trade accounts receivable
|
|
4,469,804
|
|
|
4,102,018
|
|
Other current assets
|
|
1,668,734
|
|
|
1,664,866
|
|
Total
current assets
|
|
29,022,652
|
|
|
29,581,490
|
|
|
|
|
|
|
|
|
Restricted cash and security bond reserves
|
|
18,605,059
|
|
|
20,111,350
|
|
Property, plant and equipment, net
|
|
169,622,415
|
|
|
170,301,349
|
|
Intangible assets, net
|
|
15,038,722
|
|
|
15,084,143
|
|
Net deferred income tax asset
|
|
8,211,000
|
|
|
8,346,000
|
|
Total assets
|
$
|
240,499,848
|
|
$
|
243,424,332
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities:
|
|
|
|
|
|
|
Accounts payable and
accrued liabilities
|
$
|
2,232,844
|
|
$
|
2,255,710
|
|
Current portion of notes payable
|
|
3,892,026
|
|
|
4,259,595
|
|
Total
current liabilities
|
|
6,124,870
|
|
|
6,515,305
|
|
|
|
|
|
|
|
|
Long-term Liabilities:
|
|
|
|
|
|
|
Asset retirement obligations
|
|
1,219,903
|
|
|
1,219,903
|
|
Notes payable, less
current portion
|
|
102,279,570
|
|
|
104,131,086
|
|
Total long-term liabilities
|
|
103,499,473
|
|
|
105,350,989
|
|
|
|
|
|
|
|
|
Total
liabilities
|
|
109,624,343
|
|
|
111,866,294
|
|
|
|
|
|
|
|
|
Commitments and Contingencies (note 10)
|
|
|
|
|
|
|
STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
Capital stock (authorized: 250,000,000 common shares with a
$0.001 par value; issued and outstanding shares at March 31, 2017 and
December 31, 2016 were: 19,039,435and 18,970,445; respectively)
|
|
19,039
|
|
|
18,970
|
|
Additional paid-in capital
|
|
122,448,633
|
|
|
121,933,378
|
|
Accumulated deficit
|
|
(16,713,410
|
)
|
|
(16,974,300
|
)
|
|
|
105,754,262
|
|
|
104,978,048
|
|
|
|
|
|
|
|
|
Non-controlling interests
|
|
25,121,243
|
|
|
26,579,990
|
|
Total stockholders equity
|
|
130,875,505
|
|
|
131,558,038
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
$
|
240,499,848
|
|
$
|
243,424,332
|
|
The accompanying notes are an integral part of these
consolidated financial statements.
-4-
U.S. GEOTHERMAL INC.
CONSOLIDATED STATEMENTS OF INCOME
|
|
(Unaudited)
|
|
|
|
For
the Three Months Ended March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
|
|
|
|
|
|
Plant Revenues:
|
|
|
|
|
|
|
Energy sales
|
$
|
8,334,450
|
|
$
|
8,410,822
|
|
Energy credit sales
|
|
102,619
|
|
|
92,454
|
|
Total plant operating revenues
|
|
8,437,069
|
|
|
8,503,276
|
|
|
|
|
|
|
|
|
Plant Expenses:
|
|
|
|
|
|
|
Plant production expenses
|
|
2,946,072
|
|
|
2,398,716
|
|
Depreciation and
amortization
|
|
1,632,748
|
|
|
1,580,863
|
|
Total plant operating expenses
|
|
4,578,820
|
|
|
3,979,579
|
|
|
|
|
|
|
|
|
Gross Profit
|
|
3,858,249
|
|
|
4,523,697
|
|
Operating Expenses:
|
|
|
|
|
|
|
Corporate administration
|
|
303,706
|
|
|
354,046
|
|
Professional and
management fees
|
|
145,765
|
|
|
1,056,509
|
|
Employee compensation
|
|
911,734
|
|
|
806,669
|
|
Promotion
|
|
36,835
|
|
|
83,412
|
|
Exploration
|
|
28,190
|
|
|
21,266
|
|
Operating Income
|
|
2,432,019
|
|
|
2,201,795
|
|
|
|
|
|
|
|
|
Other (income) expenses:
|
|
|
|
|
|
|
Interest expense
|
|
1,188,271
|
|
|
933,692
|
|
Other (income)
expense
|
|
(14,738
|
)
|
|
(9,692
|
)
|
|
|
|
|
|
|
|
Income Before Income Tax Expense
|
|
1,258,486
|
|
|
1,277,795
|
|
Income tax expense
|
|
135,000
|
|
|
90,000
|
|
|
|
|
|
|
|
|
Net Income
|
|
1,123,486
|
|
|
1,187,795
|
|
|
|
|
|
|
|
|
Net income attributable to the non-controlling interests
|
|
(862,596
|
)
|
|
(1,036,403
|
)
|
|
|
|
|
|
|
|
Net Income Attributable to U.S. Geothermal Inc.
|
$
|
260,890
|
|
$
|
151,392
|
|
|
|
|
|
|
|
|
Net Earnings Per Share
Attributable to U.S. Geothermal Inc.:
|
|
|
|
|
|
|
Basic
|
$
|
0.01
|
|
$
|
0.01
|
|
Diluted
|
|
0.01
|
|
|
0.01
|
|
|
|
|
|
|
|
|
Weighted average number of
shares used in the calculation of income per share:
|
|
|
|
|
|
|
Basic
|
|
18,951,468
|
|
|
18,233,778
|
|
Diluted
|
|
19,285,288
|
|
|
18,547,035
|
|
The accompanying notes are an integral part of these
consolidated financial statements.
-5-
U.S. GEOTHERMAL INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
(Unaudited)
|
|
|
|
For
the Three Months Ended March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
|
|
|
|
|
|
Operating Activities:
|
|
|
|
|
|
|
Net Income
|
$
|
1,123,486
|
|
$
|
1,187,795
|
|
Adjustments to reconcile net income to total
cash provided by operating activities:
|
|
|
|
|
|
|
Depreciation and amortization
|
|
1,689,173
|
|
|
1,613,521
|
|
Stock based compensation
|
|
324,690
|
|
|
277,315
|
|
Change in deferred income taxes
|
|
135,000
|
|
|
90,000
|
|
Net changes in:
|
|
|
|
|
|
|
Trade accounts receivable
|
|
(367,786
|
)
|
|
1,407,371
|
|
Accounts payable and accrued liabilities
|
|
40,533
|
|
|
478,507
|
|
Prepaid expenses and other
|
|
(3,868
|
)
|
|
(50,810
|
)
|
Total cash provided by operating activities
|
|
2,941,228
|
|
|
5,003,699
|
|
|
|
|
|
|
|
|
Investing Activities:
|
|
|
|
|
|
|
Purchases
of property, plant and equipment
|
|
(1,269,749
|
)
|
|
(1,501,101
|
)
|
Grant reimbursement on
construction
|
|
270,856
|
|
|
-
|
|
Net
proceeds from (funding of) restricted cash reserves and bonds
|
|
218,617
|
|
|
(110,955
|
)
|
Total cash used by investing activities
|
|
(780,276
|
)
|
|
(1,612,056
|
)
|
|
|
|
|
|
|
|
Financing Activities:
|
|
|
|
|
|
|
Issuance
of common stock
|
|
190,634
|
|
|
1,258,385
|
|
Distributions to
non-controlling interest
|
|
(2,321,343
|
)
|
|
(2,451,484
|
)
|
Principal
payments on notes payable and other obligations
|
|
(2,248,409
|
)
|
|
(3,421,317
|
)
|
Total cash used by financing activities
|
|
(4,379,118
|
)
|
|
(4,614,416
|
)
|
|
|
|
|
|
|
|
Decrease in Cash and Cash Equivalents
|
|
(2,218,166
|
)
|
|
(1,222,773
|
)
|
|
|
|
|
|
|
|
Cash and Cash Equivalents, Beginning of
Year
|
|
15,287,144
|
|
|
8,654,375
|
|
|
|
|
|
|
|
|
Cash and Cash Equivalents, End of Year
|
$
|
13,068,978
|
|
$
|
7,431,602
|
|
|
|
|
|
|
|
|
Supplemental Disclosures:
|
|
|
|
|
|
|
Non-cash investing and
financing activities:
|
|
|
|
|
|
|
Accrual for purchases of
property and equipment
|
$
|
63,399
|
|
$
|
803,144
|
|
|
|
|
|
|
|
|
Other Items:
|
|
|
|
|
|
|
Interest
paid
|
|
1,855,640
|
|
|
1,361,349
|
|
The accompanying notes are an integral part of these
consolidated financial statements.
-6-
U.S. GEOTHERMALINC.
CONSOLIDATED STATEMENTS OF CHANGES
IN STOCKHOLDERS EQUITY - Unaudited
For the Three Months Ended March 31, 2017 and Year
Ended December 31, 2016
|
|
|
|
|
|
|
|
Additional
|
|
|
|
|
|
Non-
|
|
|
|
|
|
|
Number of
|
|
|
Common
|
|
|
Paid-In
|
|
|
Accumulated
|
|
|
controlling
|
|
|
|
|
|
|
Shares
|
|
|
Shares
|
|
|
Capital
|
|
|
Deficit
|
|
|
Interest
|
|
|
Totals
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at January 1, 2016
|
|
17,933,570
|
|
$
|
17,933
|
|
$
|
118,220,681
|
|
$
|
(17,437,631
|
)
|
$
|
27,611,924
|
|
$
|
128,412,907
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributions to non-controlling interest
entities
|
|
-
|
|
|
-
|
|
|
-
|
|
|
-
|
|
|
(4,153,951
|
)
|
|
(4,153,951
|
)
|
Stock issued under At Market Issuance Purchase Agreement
net of commitment shares valued at $225,000
|
|
410,635
|
|
|
411
|
|
|
1,188,224
|
|
|
-
|
|
|
-
|
|
|
1,188,634
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock issued by the exercise of employee stock options
|
|
342,082
|
|
|
342
|
|
|
882,961
|
|
|
-
|
|
|
-
|
|
|
883,303
|
|
Stock issued by the exercise of broker and
stock purchase warrants
|
|
209,240
|
|
|
209
|
|
|
587,806
|
|
|
|
|
|
|
|
|
588,015
|
|
Stock compensation
|
|
74,918
|
|
|
75
|
|
|
1,053,706
|
|
|
-
|
|
|
-
|
|
|
1,053,782
|
|
Net income
|
|
-
|
|
|
-
|
|
|
-
|
|
|
463,331
|
|
|
3,122,017
|
|
|
3,585,348
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2016
|
|
18,970,445
|
|
|
18,970
|
|
|
121,933,378
|
|
|
(16,974,300
|
)
|
|
26,579,990
|
|
|
131,558,038
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributions to non-controlling interest
entities
|
|
-
|
|
|
-
|
|
|
-
|
|
|
-
|
|
|
(2,321,343
|
)
|
|
(2,321,343
|
)
|
Stock issued by the exercise of employee stock options
|
|
24,999
|
|
|
24
|
|
|
55,472
|
|
|
-
|
|
|
-
|
|
|
55,496
|
|
Stock issued by the exercise of stock
purchase warrants
|
|
45,046
|
|
|
45
|
|
|
135,093
|
|
|
-
|
|
|
-
|
|
|
135,138
|
|
Stock compensation
|
|
(1,055
|
)
|
|
-
|
|
|
324,690
|
|
|
-
|
|
|
-
|
|
|
324,690
|
|
Net income
|
|
-
|
|
|
-
|
|
|
-
|
|
|
260,890
|
|
|
862,596
|
|
|
1,123,486
|
|
Balance at March 31, 2017
|
|
19,039,435
|
|
$
|
19,039
|
|
$
|
122,448,633
|
|
$
|
(16,713,410
|
)
|
$
|
25,121,243
|
|
$
|
130,875,505
|
|
The accompanying notes are an integral part of these
consolidated financial statements.
-7-
U.S. GEOTHERMAL INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - Unaudited
March 31, 2017
NOTE 1 - ORGANIZATION AND DESCRIPTION OF BUSINESS
U.S. Geothermal Inc. (the Company) was incorporated on March
10, 2000 in the State of Delaware. U.S. Geothermal Inc. Idaho was formed in
February 2002, and is the primary subsidiary through which the Company conducts
its operations. The Company constructs, owns, manages and operates power plants
that utilize geothermal resources to produce renewable energy. The Companys
operations have been, primarily, focused in the United States and Central
America.
Basis of Presentation
These unaudited interim consolidated financial statements of
the Company and its subsidiaries have been prepared in accordance with the rules
and regulations of the Securities and Exchange Commission (SEC) for interim
financial reporting. Certain information and footnote disclosures normally
included in the annual consolidated financial statements prepared in accordance
with U.S. generally accepted accounting principles (GAAP) have been condensed
or omitted pursuant to such rules and regulations. In our opinion, the unaudited
consolidated financial statements include all material adjustments, all of which
are of a normal and recurring nature, necessary to present fairly our financial
position as of March 31, 2017 and our operating results and cash flows for the
three months ended March 31, 2017 and 2016. The accompanying financial
information as of December 31, 2016, is derived from audited financial
statements. Interim results are not necessarily indicative of results for a full
year. The information included in this Quarterly Report on Form 10-Q should be
read in conjunction with our Annual Report on Form 10-K for the year ended
December 31, 2016.
The Company consolidates subsidiaries that it controls
(more-than-50% owned) and entities over which control is achieved through means
other than voting rights. These consolidated financial statements include the
accounts of the Company and its wholly owned subsidiaries, as well as three
controlling interests. The accounts of the following companies are consolidated
in these financial statements:
|
i)
|
U.S. Geothermal Inc. (incorporated in the State of
Delaware);
|
|
ii)
|
U.S. Geothermal Inc. (incorporated in the State of
Idaho);
|
|
iii)
|
U.S. Geothermal Services, LLC (organized in the State of
Delaware);
|
|
iv)
|
Nevada USG Holdings, LLC (organized in the State of
Delaware);
|
|
v)
|
USG Nevada LLC (organized in the State of
Delaware);
|
|
vi)
|
Nevada North USG Holdings, LLC (organized in the State of
Delaware);
|
|
vii)
|
USG Nevada North, LLC (organized in the State of
Delaware);
|
|
viii)
|
Oregon USG Holdings, LLC (organized in the State of
Delaware);
|
|
ix)
|
USG Oregon LLC (organized in the State of
Delaware);
|
|
x)
|
Raft River Energy I LLC (organized in the State of
Delaware);
|
|
xi)
|
Gerlach Geothermal LLC (organized in the State of
Delaware);
|
|
xii)
|
USG Gerlach LLC (organized in the State of
Delaware);
|
|
xiii)
|
U.S. Geothermal Guatemala, S.A. (organized in
Guatemala);
|
|
xiv)
|
Geysers USG Holdings Inc. (incorporated in the State of
Delaware);
|
|
xv)
|
Western GeoPower, Inc. (incorporated in the State of
California);
|
|
xvi)
|
USG Mayacamas Inc. (incorporated in the State of
Delaware));
|
|
xvii)
|
Mayacamas Energy LLC (organized in the State of
California);
|
|
xviii)
|
Skyline Geothermal LLC (organized in the State of
Delaware);
|
|
xix)
|
Skyline Geothermal Holding, Inc. (incorporated in the
State of Delaware);
|
|
xx)
|
Earth Power Resources Inc. (incorporated in Delaware);
and
|
|
xxi)
|
Idaho USG Holdings LLC (organized in the State of
Delaware).
|
-8-
All intercompany transactions are eliminated upon
consolidation.
In cases where the Company owns a majority interest in an
entity but does not own 100% of the interest in the entity, it recognizes a
non-controlling interest attributed to the interest controlled by outside third
parties. The Company will recognize 100% of the assets and liabilities of the
entity, and disclose the non-controlling interest. The consolidated statements
of income and comprehensive income will consolidate the subsidiarys full
operations, and will separately disclose the elimination of the non-controlling
interests allocation of profits and losses.
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Cash and Cash Equivalents
The Company considers all unrestricted cash and short-term
deposits, with original maturities of no more than ninety days when acquired to
be cash and cash equivalents.
Trade Accounts Receivable Allowance for Doubtful
Accounts
Management estimates the amount of trade accounts receivable
that may not be collectible and records an allowance for doubtful accounts. The
allowance is an estimate based upon aging of receivable balances, historical
collection experience, and the periodic credit evaluations of our customers
financial condition. Receivable balances are written off when we determine that
the balance is uncollectible. As of March 31, 2017 and December 31, 2016, there
were no balances that were over 90 days past due and no balance in allowance for
doubtful accounts was recognized.
Concentration of Credit Risk
The Companys cash and cash equivalents, including restricted
cash, consisted of commercial bank deposits, money market accounts, and petty
cash. Cash deposits are held in commercial banks in Boise, Idaho and Portland,
Oregon. Deposits are guaranteed by the Federal Deposit Insurance Corporation
(FDIC) up to $250,000 per legal entity. At March 31, 2017, the Companys total
cash balance, excluding money market funds, was $7,376,783 and bank deposits
amounted to $7,830,480. The primary difference was due to outstanding checks and
deposits. Of the bank deposits, $6,514,547 was not covered by or was in excess
of FDIC insurance guaranteed limits. At March 31, 2017, the Companys money
market funds invested, primarily, in government backed securities totaled
$32,639,791 and were not subject to deposit insurance. A contracted power
purchaser held a security bond for the Company that totaled $1,468,898 at March
31, 2017.
Property, Plant and Equipment
Property, plant and equipment, including assets under capital
lease, are recorded at historical cost. Costs of acquisition of geothermal
properties are capitalized in the period of acquisition. Major improvements that
significantly increase the useful lives and/or capabilities of the assets are
capitalized. A primary factor in determining whether to capitalize construction
type costs is the stage of the potential projects development. Once a project
is determined to be commercially viable, all costs directly associated with the
development and construction of the project are capitalized. Until that time,
all development costs are expensed. A commercially viable project will typically
have, among other factors, a reservoir discovery well or other significant
geothermal surface anomaly, a power transmission path that is identified and
available, and an electricity off-taker identified. A valid reservoir discovery
is generally defined when a test well has been substantially completed that
indicates the presence of a geothermal reservoir that has a high probability of
possessing the necessary temperatures, permeability, and flow rates. After a
valid discovery has been made, the project enters the development stage.
Generally, all costs incurred during the development stage are capitalized and
tracked on an individual project basis and are included in construction in progress until the project has been placed into
service. If a geothermal project is abandoned, the associated costs that have
been capitalized are charged to expense in the year of abandonment. Expenditures
for repairs and maintenance are charged to expense as incurred. Interest costs
incurred during the construction period of defined major projects from debt that
is specifically incurred for those projects are capitalized. Funds received from
grants associated with capital projects reduce the cost of the asset directly
associated with the individual grants. The offset of the cost of the asset
associated with grant proceeds is recorded in the period when the requirements
of the grant are substantially complete and the amount can be reasonably
estimated.
-9-
Direct labor costs, incurred for specific major projects
expected to have long-term benefits will be capitalized. Direct labor costs
subject to capitalization include employee salaries, as well as, related payroll
taxes and benefits. With respect to the allocation of salaries to projects,
salaries are allocated based on the percentage of hours that our key managers,
engineers and scientists work on each project and are invoiced to the project
each month. These individuals track their time worked at each project. Major
projects are, generally, defined as projects expected to exceed $500,000. Direct
labor includes all of the time incurred by employees directly involved with
construction and development activities. General and/or indirect management time
and time spent evaluating the feasibility of potential projects is expensed when
incurred. Employee training time is expensed when incurred.
Depreciation is calculated on a straight-line basis over the
estimated useful life of the asset. Where appropriate, terms of property rights
and revenue contracts can influence the determination of estimated useful lives.
Estimated useful lives in years by major asset categories are summarized as
follows:
|
|
Estimated Useful
|
Asset Categories
|
|
Lives in Years
|
|
|
|
Furniture, vehicle and other equipment
|
|
3 to 5
|
Power plant, buildings and improvements
|
|
3 to 30
|
Wells
|
|
30
|
Well pumps and components
|
|
5 to 15
|
Pipelines
|
|
30
|
Transmission lines
|
|
30
|
Stock Compensation
The Company accounts for stock based compensation by recording
the estimated fair value of stock-based awards granted as compensation expense
over the vesting period, net of estimated forfeitures. The fair value of
restricted stock awards is determined based on the number of shares granted and
the quoted price of the Companys common stock on the date of grant. The fair
value of stock option awards is estimated at the grant date as calculated by the
Black-Scholes-Merton option pricing model. Stock-based compensation expense is
attributed to earnings for stock options and restricted stock on the
straight-line method. The Company estimates forfeitures of stock-based awards
based on historical experience and expected future activity.
Earnings Per Share
Basic income or loss per share is computed using the weighted
average number of common shares outstanding during the period, and excludes any
dilutive effects of common stock equivalent shares, such as options and
restricted stock awards. Restricted stock awards (RSAs) are considered
outstanding and included in the computation of basic income or loss per share
when underlying restrictions expire and the awards are no longer forfeitable.
Diluted income per share is computed using the weighted average number of common
shares outstanding and common stock equivalent shares outstanding during the
period using the treasury stock method. Common stock equivalent shares are
excluded from the computation if their effect is anti-dilutive.
-10-
Revenue
Revenue Recognition
Energy Sales
The energy sales revenue is recognized
when the electrical power generated by the Companys power plants is delivered
to the customer who is reasonably assured to be able to pay under the terms
defined by the Power Purchase Agreements (PPAs).
Renewable Energy Credits (RECs)
Currently, the
Company operates three plants that produce renewable energy that creates a right
to a REC. The Company earns one REC for each megawatt hour produced from the
geothermal power plant. The Company considers the RECs to be outputs that are an
economic benefit obtained directly through the operation of the plants. The
Company does not currently hold any RECs for our own use. Revenues from RECs
sales are recognized when the Company has met the terms and conditions of
certain energy sales agreements with a financially capable buyer. At Raft River
Energy I LLC (RREI), each REC is certified by the Western Electric
Coordinating Council and sold under a REC Purchase and Sales Agreement to Holy
Cross Energy. At San Emidio and Neal Hot Springs, the RECs are owned by our
customer and are bundled with energy sales. At all three plants, title for the
RECs pass during the same month as energy sales. As a result, costs associated
with the sale of RECs are not segregated on the consolidated statements of
income.
Revenue Source
All of the Companys operating revenues (energy sales and REC
sales) originate from energy production from its interests in three geothermal
power plants located in the states of Idaho, Oregon and Nevada.
Recent Accounting Pronouncements
Management has considered all recent accounting pronouncements.
The following pronouncements were deemed applicable to our financial statements:
Statement of Cash Flows
In August
2016, FASB issued Accounting Standards Update No. 2016-15 (Update 2016-15)
,
Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and
Cash Payments.
In November 2016, FASB issued Accounting Standards Update No.
2016-18 (Update 2016-18),
Statement of Cash Flows (Topic 230),
Restricted Cash.
Update 2016-15 provides guidance on how certain cash
receipts and cash payments are presented and classified in the statement of cash
flows. Update 2016-18 provides guidance on how to classify and present changes
in restricted cash or restricted cash equivalents that occur when there are
direct cash receipts into restricted cash or restricted cash equivalents or
direct cash payments made from restricted cash or restricted cash equivalents.
These Updates are effective for annual periods beginning after December 15,
2017, and interim periods within those fiscal years. Early adoption is
permitted, including adoption in an interim period. It is likely that some of
the provisions of Update 2016-15 will apply to certain transactions our Company
may engage in. The Company holds restricted cash and restricted cash equivalents
that are addressed in Update 2016-18. Management is currently evaluating the
possible impact these Updates may have on the presentation of the Companys
consolidated statements of cash flows.
Revenue Recognition
In May 2014, FASB
issued Accounting Standards Update No. 2014-09 (Update 2014-09),
Revenue
from Contracts with Customers (Topic 606).
Update 2014-09 amends the revenue
recognition guidance and requires more detailed disclosures to enable financial
statement users to understand the nature, amount, timing and uncertainties of
revenue and cash flows arising from contracts with customers
.
In April
2016, FASB issued Accounting Standards Update No. 2016-10 (Update 2016-10),
Revenue from
Contracts with Customers (Topic 606), Identify Performance
Obligations and Licensing.
In March 2016, FASB issued Accounting Standards
Update No. 2016-08 (Update 2016-08),
Revenue from Contracts with Customers
(Topic 606), Principal versus Agent Considerations (Reporting Revenue Gross
versus Net).
In May 2016, FASB issued Accounting Standards Update No.
2016-12 (Updated 2016-12),
Revenue from Contracts with Customers (Topic 606),
Narrow-Scope Improvements and Practical Expedients.
Both Update 2016-10 and
2016-08 provide additional guidance on how an entity should recognize revenue
when depicting the transfer of promised goods or services. These Updates provide
more guidance on identifying performance obligations and licensing. Update
2016-12 provides additional clarification to the steps an entity should follow
to achieve the core principle of Topic 606. The guidance, as amended, is
effective for annual and interim reporting periods beginning after December 15,
2017, with early adoption permitted for public companies effective from annual
and interim reporting periods beginning after December 31, 2016. Management has
reviewed the essential provisions of all of our major revenue contracts and our
revenue recognition practices. As a result of this review, Management does not
expect a material impact on the consolidated statement of income.
-11-
Leases
In February 2016, the Financial
Accounting Standards Board (FASB) issued Accounting Standards Update No.
2016-02 (Update 2016-02),
Leases (Topic 842).
Update 2016-02 recognizes
lease assets and lease liabilities on the balance sheet and requires disclosing
key information about leasing arrangements. Under previous standards, assets and
liabilities were only recognized for leases that met the definition of a capital
lease. Our preliminary review indicates that certain of the Companys lease
contracts would be subject to the reporting requirements defined by Update
2016-02. The Update is effective for public companies with fiscal years
beginning after December 15, 2018, including interim periods within those fiscal
years. Early adoption is permitted. In transition, the Company would be required
to recognize and measure leases at the beginning of the earliest period being
presented using a modified retrospective approach. Management is still
evaluating the possible impact this Update may have on the financial
presentation of the Companys consolidated financial statements.
Stock Compensation
In March 2016, FASB
issued Accounting Standards Update No. 2016-09 (Update 2016-09),
Compensation-Stock Compensation (Topic 718), Improvements to Employee
Share-Based Payment Accounting.
Update 2016-09 provides guidance designed to
simplify of the accounting treatment of certain matters surrounding share-based
compensation. Update 2016-09 is effective for annual periods beginning after
December 15, 2016, and interim periods within those annual periods. Changes
related to the timing of when excess tax benefits are recognized, minimum
statutory withholding requirements, forfeitures, and intrinsic value should be
applied using a modified retrospective transition method by means of
cumulative-effect adjustment to equity as of the beginning of the period in
which the guidance is adopted. This Update was adopted during the current
quarter with minimal impact on the financial presentation of the Companys
consolidated financial statements.
NOTE 3 RESTRICTED CASH AND BOND RESERVES
Under the terms of the loan agreements with the U.S. Department
of Energy and Prudential Capital Group, various bond and cash reserves are
required to provide assurances that the power plants will have the necessary
funds to maintain expected operations and meet loan payment obligations.
Restricted cash balances and bond reserves are summarized as follows:
-12-
Current restricted cash and bond reserves
:
|
|
|
March 31,
|
|
|
December 31,
|
|
Restricting Entities/Purpose
|
|
|
2017
|
|
|
2016
|
|
Idaho Department of Water
Resources, Geothermal Well Bond
|
|
$
|
260,000
|
|
$
|
260,000
|
|
Bureau of Land Management, Geothermal Lease
Bond- Gerlach
|
|
|
10,000
|
|
|
10,000
|
|
State of Nevada Division of
Minerals, Statewide Drilling Bond
|
|
|
50,000
|
|
|
50,000
|
|
Bureau of Land Management, Geothermal Lease
Bonds- USG Nevada
|
|
|
150,000
|
|
|
150,000
|
|
Oregon Department of Geology
and Mineral Industries, Mineral Land and Reclamation Program
|
|
|
400,000
|
|
|
400,000
|
|
Prudential Capital Group, Cash Reserves
|
|
|
502,994
|
|
|
284,621
|
|
Prudential Capital Group,
Debt Service Reserves (USG Nevada LLC)
|
|
|
1,602,032
|
|
|
1,600,597
|
|
Bureau of Land Management , Geothermal Rights
Lease Bond
|
|
|
10,000
|
|
|
10,000
|
|
U.S. Department of Energy,
Debt Service Reserve
|
|
|
793,314
|
|
|
2,011,445
|
|
State of California Division of Oil, Gas and
Geothermal Resources, Well Cash Bond
|
|
|
100,000
|
|
|
100,000
|
|
Prudential Capital Group,
Debt Service Reserves (Idaho USG Holdings LLC)
|
|
|
1,755,776
|
|
|
1,755,776
|
|
Prudential Capital Group, Revenue Reserves
(Idaho USG Holdings LLC)
|
|
|
2,285,836
|
|
|
-
|
|
CAISO, Transmission
Interconnection Escrow Deposits
|
|
|
1,895,184
|
|
|
1,895,023
|
|
|
|
|
|
|
|
|
|
|
|
$
|
9,815,136
|
|
$
|
8,527,462
|
|
-13-
Long-term restricted cash and bond reserves:
|
|
|
March 31,
|
|
|
December 31,
|
|
Restricting Entities/Purpose
|
|
|
2017
|
|
|
2016
|
|
Nevada Energy, PPA Security
Bond
|
|
$
|
1,468,898
|
|
$
|
1,468,898
|
|
Prudential Capital Group, Maintenance
Reserves (USG Nevada LLC)
|
|
|
1,063,147
|
|
|
1,081,744
|
|
Prudential Capital Group,
Well Reserves (USG Nevada LLC)
|
|
|
1,111,017
|
|
|
951,486
|
|
Prudential Capital Group, Maintenance
Reserves (Idaho USG Holdings LLC)
|
|
|
1,807,890
|
|
|
1,807,890
|
|
Prudential Capital Group,
Capital Expenditure Reserves (Raft River Energy I LLC)
|
|
|
3,796
|
|
|
3,796
|
|
U.S. Department of Energy, Operations
Reserves
|
|
|
270,000
|
|
|
270,000
|
|
U.S. Department of Energy,
Debt Service Reserves
|
|
|
2,380,007
|
|
|
2,413,951
|
|
U.S. Department of Energy, Short Term Well
Field Reserves
|
|
|
4,509,013
|
|
|
4,508,650
|
|
U.S. Department of Energy,
Long-Term Well Field Reserves
|
|
|
3,533,621
|
|
|
5,175,777
|
|
U.S. Department of Energy, Capital
Expenditure Reserves
|
|
|
2,457,670
|
|
|
2,429,158
|
|
|
|
|
|
|
|
|
|
|
|
$
|
18,605,059
|
|
$
|
20,111,350
|
|
The well bonding requirements ensure that the Company has
sufficient financial resources to construct, operate and maintain geothermal
wells while safeguarding subsurface, surface and atmospheric resources from
unreasonable degradation, and to protect ground water aquifers and surface water
sources from contamination. The debt service reserves are required to provide
assurance that the Company will have sufficient funds to meet its debt payment
obligations for the terms specified by the loan agreements. The maintenance and
capital expenditure reserves are required by the lending entities to ensure that
funds are available to acquire and maintain critical components of power plants
and related supporting structures to enable the plants to operate according to
expectations. Except for the PPA Security Bond, all of the restricted funds
consisted of cash deposits or money market accounts held in commercial banks.
Portions of the cash deposits are subject to FDIC insurance (see note 2 for
details). The PPA Security Bond is held by the power purchaser. All of the
reserve accounts were considered to be fully funded at March 31, 2017 and
December 31, 2016.
NOTE 4 TRADE RECEIVABLES/INSURANCE PROCEEDS
The Companys receivables are summarized as follows:
|
|
March 31,
|
|
|
December 31,
|
|
|
|
2017
|
|
|
2016
|
|
Trade receivables
|
$
|
2,430,338
|
|
$
|
4,100,747
|
|
Insurance proceeds receivable
|
|
2,037,409
|
|
|
-
|
|
Other receivables
|
|
2,057
|
|
|
1,271
|
|
|
|
|
|
|
|
|
|
$
|
4,469,804
|
|
$
|
4,102,018
|
|
On January 5, 2017, Unit I of the USG Oregon LLC plant
experienced mechanical failures, primarily due to extreme cold temperatures,
that resulted in an outage and the loss of a substantial amount of the plants
refrigerant. The initial repairs to identify and plug the damaged tubes were
completed on February 12, 2017 and the Unit was returned to service. Unit I is
operating at a reduced level until the plugged heat exchanger tubes can be
replaced during the annual maintenance outage scheduled for May 2017. The repair
costs and lost revenue were covered by property and business interruption
insurance, subject to deductibles and other terms of the policy. The deductibles
were $50,000 for property loss and a 30 day period for business interruption
coverage. The lost revenue associated with that 30 day deductible period is
estimated at $833,000. At March 31, 2017, the total submitted claims that
are expected to be recovered after deductibles were $2,037,409. The Company
estimates that the full amount of the property loss expenses, less the $50,000
deductible, will be collected. The Company received partial reimbursement of
repair costs that totaled $1,050,000 in April 2017. For the three months ended
March 31, 2017, insurance recovery amounts of $1,712,003 for plant production
expenses and $325,406 for energy sales were accrued.
-14-
NOTE 5 - PROPERTY, PLANT AND EQUIPMENT
During the three months ended March 31, 2017, the Company
focused on development activities at Raft River Energy I, San Emidio Phase II
and WGP Geysers projects. At Raft River, a new production well was connected to
the plant and placed into operation on March 21, 2017 at a cost of approximately
$507,000. At San Emidio Phase II and Crescent Valley projects, seismic studies
were conducted and capitalized that cost approximately $322,000 in the current
quarter. Grant proceeds totaling $444,026 offset the majority of the total costs
of the studies. Costs during the quarter that totaled $400,338 were capitalized
at WGP Geysers for plant engineering and interconnection costs.
Property, plant and equipment, at cost, are summarized as
follows:
|
|
March 31,
|
|
|
December 31,
|
|
|
|
2017
|
|
|
2016
|
|
Land
|
$
|
3,116,262
|
|
$
|
3,116,262
|
|
Power production plant
|
|
159,876,162
|
|
|
159,876,162
|
|
Grant proceeds for power
plants
|
|
(52,965,236
|
)
|
|
(52,965,236
|
)
|
Wells
|
|
71,273,114
|
|
|
71,340,305
|
|
Grant proceeds for wells
|
|
(3,464,555
|
)
|
|
(3,464,555
|
)
|
Furniture and equipment
|
|
4,515,537
|
|
|
4,491,058
|
|
|
|
182,351,284
|
|
|
182,393,996
|
|
|
|
|
|
|
|
|
Less: accumulated depreciation
|
|
(38,830,813
|
)
|
|
(37,216,385
|
)
|
|
|
143,520,471
|
|
|
145,177,611
|
|
Construction in progress
|
|
26,101,944
|
|
|
25,123,738
|
|
|
|
|
|
|
|
|
|
$
|
169,622,415
|
|
$
|
170,301,349
|
|
Depreciation expense charged to plant operations and
administrative costs for the three months ended March 31, 2017 and 2016, was
$1,614,428 and $1,568,100; respectively.
Changes in construction in progress are summarized as follows:
|
|
For the Three
|
|
|
For the Year
|
|
|
|
Months Ended
|
|
|
Ended December
|
|
|
|
March 31, 2017
|
|
|
31,
2016
|
|
Beginning balances
|
$
|
25,123,738
|
|
$
|
21,022,981
|
|
Development/construction
|
|
1,484,764
|
|
|
8,116,725
|
|
Grant
reimbursement
|
|
(444,026
|
)
|
|
-
|
|
Placed into operation
|
|
(62,532
|
)
|
|
(4,015,968
|
)
|
Ending balances
|
$
|
26,101,944
|
|
$
|
25,123,738
|
|
-15-
Constructions in Progress, at cost, consisting of the following
projects/assets by location are as follows:
|
|
March 31,
|
|
|
December 31,
|
|
|
|
2017
|
|
|
2016
|
|
Raft River, Idaho:
|
|
|
|
|
|
|
Unit I, well
improvements
|
$
|
491,626
|
|
$
|
5,377
|
|
Unit I, plant improvements
|
|
129,969
|
|
|
108,555
|
|
Unit II, power
plant, substation and transmission lines
|
|
751,618
|
|
|
751,618
|
|
Unit II, well construction
|
|
2,150,177
|
|
|
2,149,835
|
|
|
|
3,523,390
|
|
|
3,015,385
|
|
San Emidio, Nevada:
|
|
|
|
|
|
|
Unit II,
power plant, substation and transmission lines
|
|
432,945
|
|
|
426,941
|
|
Unit II, well construction
|
|
4,669,255
|
|
|
4,748,924
|
|
|
|
5,102,200
|
|
|
5,175,865
|
|
Neal Hot Springs, Oregon:
|
|
|
|
|
|
|
Power plant and facilities
|
|
73,980
|
|
|
73,761
|
|
Well construction
|
|
456,273
|
|
|
378,098
|
|
|
|
530,253
|
|
|
451,859
|
|
|
|
|
|
|
|
|
WGP Geysers, California:
|
|
|
|
|
|
|
Power plant and facilities
|
|
325,989
|
|
|
325,989
|
|
Well construction
|
|
9,265,430
|
|
|
8,865,093
|
|
|
|
9,591,419
|
|
|
9,191,082
|
|
Crescent Valley, Nevada:
|
|
|
|
|
|
|
Well construction
|
|
1,613,346
|
|
|
1,655,653
|
|
El Ceibillo, Republic of Guatemala:
|
|
|
|
|
|
|
Well construction
|
|
5,732,836
|
|
|
5,625,394
|
|
Plant and
facilities
|
|
8,500
|
|
|
8,500
|
|
|
|
5,741,336
|
|
|
5,633,894
|
|
|
|
|
|
|
|
|
|
$
|
26,101,944
|
|
$
|
25,123,738
|
|
-16-
NOTE 6 INCOME TAXES
The Companys estimated effective income tax rates are as
follows:
|
|
For the Three Months Ended
|
|
|
|
March 31,
|
|
|
|
2017
|
|
|
2016
|
|
U.S. Federal statutory rate
|
|
34.0%
|
|
|
34.0%
|
|
Average State and foreign income tax, net of
federal tax effect
|
|
2.8
|
|
|
3.5
|
|
Impact of state deferred rate
decrease
|
|
|
|
|
-
|
|
Stock based compensation
|
|
(3.8
|
)
|
|
-
|
|
Other
|
|
(0.3
|
)
|
|
-
|
|
Consolidated tax rate before non-controlling interest
|
|
32.7
|
|
|
37.5
|
|
Tax effect of non-controlling
interests
|
|
(22.0
|
)
|
|
(30.5
|
)
|
Net
effective tax rate
|
|
10.7%
|
|
|
7.0%
|
|
The provision for income taxes reflects an estimated effective
income tax rate attributable to U.S. Geothermal Inc.s share of income. Our
provision for income taxes for the three months ended March 31, 2017, reflects a
reported effective tax rate of 10.7%, which differs from the statutory federal
income tax rate of 34.0% primarily due to the impact of the non-controlling
interest, stock compensation and state income taxes.
NOTE 7 NOTES PAYABLE
Prudential Capital Group Idaho USG Holdings
LLC
In May 2016, the Companys wholly owned subsidiary (Idaho USG
Holdings LLC) entered into a loan agreement with the Prudential Capital Group to
finance the Companys development activities. The original principal totaled $20
million and included the option to issue additional debt up to $50 million
within the next two years. The original $20 million loan amount bears interest
at a fixed interest rate of 5.8% per annum. The principal and interest payments
are due semi-annually at amounts based upon a 20-year amortization period and
the scheduled remaining balance of $16,009,495 is due in full at the end of the
7 year term. The loan is secured by the Companys ownership interests in the
Neal Hot Springs (Oregon USG Holdings LLC and USG Oregon LLC) and the Raft River
(Raft River Energy I LLC) projects. At March 31, 2017, the balance of the loan
was $19,296,475 and the net unamortized debt issuance costs associated with this
loan totaled $713,549 ($821,070, less amortized costs of $107,521).
U.S. Department of Energy USG Oregon LLC
On August 31, 2011, USG Oregon LLC (USG Oregon), a subsidiary of the
Company, completed the first funding drawdown associated with the U.S.
Department of Energy (DOE) $96.8 million loan guarantee (Loan Guarantee) to
construct its power plant at Neal Hot Springs in Eastern Oregon (the Project).
All loan advances covered by the Loan Guarantee have been made under the Future
Advance Promissory Note (the Note) dated February 23, 2011. Upon the
occurrence and continuation of an event of default under the transaction
documents, all amounts payable under the Note maybe accelerated. In connection
with the Loan Guarantee, the DOE has been granted a security interest in all of
the equity interests of USG Oregon, as well as in the assets of USG Oregon,
including a mortgage on real property interests relating to the Project site. No
additional advances are allowed under the terms of the loan. A total of 13 draws
were taken and each individual draw or tranche is considered to be a separate
loan. The loan principal is scheduled to be paid over 21.5 years from the first
scheduled payment date with semi-annual installments including interest
calculated at an aggregate fixed interest rate of 2.598%. The principal payment
amounts are calculated on a straight-line basis according to the life of the
loans and the original loan principal amounts. The principal portion of the
aggregate loan payment is adjusted as individual tranches are extinguished. The principal payments
started at $1,709,963 on February 10, 2014 and were reduced to $1,626,251 on
February 10, 2017 and continue through February 12, 2035. The loan balance at
March 31, 2017 totaled $58,545,023 (current portion $3,252,501).
-17-
Loan advances/tranches and effective annual interest rates are
detailed as follows:
|
|
|
|
|
|
Annual Interest
|
|
Description
|
|
|
Amount
|
|
|
Rate
%
|
|
Advances by date:
|
|
|
|
|
|
|
|
August
31, 2011*
|
|
$
|
2,328,422
|
|
|
2.997
|
|
September 28, 2011
|
|
|
10,043,467
|
|
|
2.755
|
|
October
27, 2011
|
|
|
3,600,026
|
|
|
2.918
|
|
December 2, 2011
|
|
|
4,377,079
|
|
|
2.795
|
|
December
21, 2011
|
|
|
2,313,322
|
|
|
2.608
|
|
January 25, 2012
|
|
|
8,968,019
|
|
|
2.772
|
|
April 26,
2012
|
|
|
13,029,325
|
|
|
2.695
|
|
May 30, 2012
|
|
|
19,497,204
|
|
|
2.408
|
|
August
27, 2012
|
|
|
7,709,454
|
|
|
2.360
|
|
December 28, 2012
|
|
|
2,567,121
|
|
|
2.396
|
|
June 10,
2013
|
|
|
2,355,316
|
|
|
2.830
|
|
July 3, 2013*
|
|
|
2,242,628
|
|
|
3.073
|
|
July 31,
2013*
|
|
|
4,026,582
|
|
|
3.214
|
|
|
|
|
83,057,965
|
|
|
|
|
Principal paid through March
31, 2017
|
|
|
(24,512,942
|
)
|
|
|
|
|
|
|
|
|
|
|
|
Loan balance at March 31,
2017
|
|
$
|
58,545,023
|
|
|
|
|
* - Individual tranches have been fully extinguished.
Prudential Capital Group USG Nevada LLC
On
September 26, 2013, the Companys wholly owned subsidiary (USG Nevada LLC)
entered into a note purchase agreement with the Prudential Capital Group to
finance the Phase I San Emidio geothermal project located in northwest Nevada.
The term of the note is approximately 24 years, and bears interest at fixed rate
of 6.75% per annum. Interest payments are due quarterly. Principal payments are
due quarterly based upon minimum debt service coverage ratios established
according to projected operating results made at the loan origination date and
available cash balances. The loan agreement is secured by USG Nevada LLCs
right, title and interest in and to its real and personal property, including
the San Emidio project and the equity interests in USG Nevada LLC. At March 31,
2017, the balance of the loan was $29,038,580 (current portion $635,999).
Auto Loan U.S. Geothermal Services
On July
28, 2016, the Companys wholly owned subsidiary (U.S. Geothermal Services)
purchased a truck with down payments that totaled $39,496 and a loan agreement
with Chrysler Capital. The loan requires total monthly payments of $313,
including interest at an average rate of 6.74% per annum until July 2018. The
note is secured by the vehicle. At March 31, 2017, the loan balance totaled
$5,067 (current portion $3,526).
-18-
Based upon the terms of the notes payable and expected
conditions that may impact some of those terms, the total estimated annual
principal payments were calculated as follows:
For the Year Ended
|
|
|
Principal
|
|
March 31,
|
|
|
Payments
|
|
2018
|
|
$
|
3,892,026
|
|
2019
|
|
|
4,231,797
|
|
2020
|
|
|
5,204,928
|
|
2021
|
|
|
4,975,747
|
|
2022
|
|
|
5,257,277
|
|
Thereafter
|
|
|
83,323,370
|
|
|
|
|
|
|
|
|
$
|
106,885,145
|
|
NOTE 8 - STOCK BASED COMPENSATION
The Company has a stock incentive plan (the Stock Incentive
Plan) for the purpose of attracting and motivating directors, officers,
employees and consultants of the Company and advancing the interests of the
Company. The Stock Incentive Plan is a 15% rolling plan approved by shareholders
in September 2013, whereby the Company can grant options to the extent of 15% of
the current outstanding common shares. Under the plan, all forfeited and
exercised options can be replaced with new offerings. As of March 31, 2017, the
Company can issue stock option grants totaling up to 2,855,915 shares. Options
are typically granted for a term of up to five years from the date of grant.
Stock options granted generally vest over a period of eighteen months, with 25%
vesting on the date of grant and 25% vesting every six months thereafter. The
Company recognizes compensation expense using the straight-line method of
amortization. Historically, the Company has issued new shares to satisfy
exercises of stock options and the Company expects to issue new shares to
satisfy any future exercises of stock options.
The following table reflects the summary of stock options
outstanding at January 1, 2017 and changes for the three months ended March 31,
2017:
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
Average
|
|
|
|
|
|
|
|
Number of
|
|
|
Exercise
|
|
|
Aggregate
|
|
|
|
|
shares under
|
|
|
Price Per
|
|
|
Intrinsic
|
|
|
|
|
options
|
|
|
Share
|
|
|
Value
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance outstanding, January
1, 2017
|
|
1,824,664
|
|
$
|
3.38
|
|
$
|
3,186,265
|
|
|
Forfeited/Expired
|
|
-
|
|
|
-
|
|
|
-
|
|
|
Exercised
|
|
(24,999
|
)
|
|
2.22
|
|
|
-
|
|
|
Granted
|
|
362,636
|
|
|
4.10
|
|
|
-
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance outstanding, March 31, 2017
|
|
2,162,301
|
|
$
|
3.52
|
|
$
|
3,932,250
|
|
The fair value of each option award is estimated on the date of
grant using the Black-Scholes option-pricing model. Expected volatilities are
based on historical volatility of the Companys stock. The Company uses
historical data to estimate option volatility within the Black-Scholes model.
The expected term of options granted represents the period of time that options
granted are expected to be outstanding, based upon past experience and future
estimates and includes data from the Plan. The risk-free rate for periods within
the expected term of the option is based upon the U.S. Treasury yield curve in
effect at the time of grant. The Company currently does not foresee the payment
of dividends in the near term.
Changes in the subjective input assumptions can materially
affect the fair value estimate and, therefore, the existing models do not
necessarily provide a reliable measure of the fair value of the Companys stock
options.
-19-
During the three months ended March 31, 2017, 24,999 stock
options exercisable at prices between $1.86 and $2.76 were exercised by
employees and former employees.
On February 1, 2017, the Company granted 16,666 stock options
to an employee exercisable at a price of $4.42 that expire on February 1, 2022.
On March 28, 2017, the Company granted 345,970 stock options to employees
exercisable at a price of $4.08 that expire on March 28, 2022.
As of March 31, 2017, there was $622,763 of total unrecognized
compensation cost related to non-vested stock option compensation arrangements
granted under the Plan. That cost is expected to be recognized over a
weighted-average period of 1.5 years.
Common Stock Compensation Plan (Restricted
Shares
)
Restricted shares are issued to the recipients when granted and
held by the Company until vested. The recipients meet the vesting requirements
by maintaining employment and good standing with the Company through the vesting
period. After vesting, there are no restrictions on the shares.
At March 31, 2017, total compensation cost related to
restricted stock granted under the Stock Plan but not yet recognized was $3,712
net of estimated forfeitures. This cost will be amortized on the straight-line
method over a period of approximately 0.25 years.
Stock Purchase Warrants
At March 31, 2017, the outstanding share purchase warrants
totaled 340,093 (385,139 warrants at December 31, 2016) with a warrant exercise
price of $3.00 per warrant and expire December 26, 2017.
On January 19, 2017, broker warrants that totaled 45,046 were
exercised by an investor at the warrant exercise price of $3.00.
NOTE 9 FAIR VALUE MEASUREMENT
U.S. generally accepted accounting principles establishes a
fair value hierarchy that prioritizes the inputs used to measure fair value. The
hierarchy gives the highest priority to unadjusted quoted prices in active
markets for identical assets or liabilities (Level 1 measurement) and the lowest
priority to unobservable inputs (Level 3 measurement).
The three levels of the fair value hierarchy are as
follows:
Level 1 Quoted prices are available in active markets for identical assets or
liabilities.
Level 2 Directly or indirectly market based inputs or observable inputs used
in models or other valuation
methodologies.
Level 3 Unobservable inputs that are not corroborated by market data. The
inputs require significant management
judgement
or estimation.
-20-
The following table discloses, by level within the fair value
hierarchy, the Companys assets and liabilities measured and reported on its
Consolidated Balance Sheet at fair value on a recurring basis:
At March 31, 2017:
|
|
Total
|
|
|
Level 1
|
|
|
Level 2
|
|
|
Level 3
|
|
Assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
Money market accounts *
|
$
|
32,639,791
|
|
$
|
32,639,791
|
|
$
|
-
|
|
$
|
-
|
|
At December 31, 2016:
|
|
Total
|
|
|
Level 1
|
|
|
Level 2
|
|
|
Level 3
|
|
Assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
Money market accounts *
|
$
|
37,347,897
|
|
$
|
37,347,897
|
|
$
|
-
|
|
$
|
-
|
|
* - Money market accounts include
both restricted and unrestricted funds.
NOTE 10 - COMMITMENTS AND CONTINGENCIES
The Companys total lease costs are summarized as follows:
|
|
For the Three Months Ended,
|
|
|
|
March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
|
|
|
|
|
|
Minimum lease payments
|
$
|
107,072
|
|
$
|
98,976
|
|
Royalty based contingent lease payments
|
|
90,096
|
|
|
99,038
|
|
|
$
|
197,167
|
|
$
|
198,014
|
|
The following is the total remaining contracted lease operating
obligations (operating leases, BLM lease agreements and office leases) for the
next five years and thereafter:
Years Ending
|
|
|
|
|
December 31,
|
|
|
Amount
|
|
|
|
|
|
|
2017
|
|
$
|
832,265
|
|
2018
|
|
|
1,015,397
|
|
2019
|
|
|
901,791
|
|
2020
|
|
|
881,712
|
|
2021
|
|
|
810,726
|
|
Thereafter
|
|
|
12,714,238
|
|
-21-
NOTE 11 JOINT VENTURES/NON-CONTROLLING INTERESTS
Non-controlling interests included on the consolidated balance
sheets of the Company are detailed as follows:
|
|
March 31,
|
|
|
December 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
|
|
|
|
|
|
Gerlach Geothermal LLC
interest held by Gerlach Green Energy, LLC
|
$
|
204,114
|
|
$
|
207,217
|
|
Oregon USG Holdings LLC interest held by
Enbridge Inc.
|
|
23,967,236
|
|
|
25,361,410
|
|
Raft River Energy I LLC
interest held by Goldman Sachs
|
|
949,893
|
|
|
1,011,363
|
|
|
$
|
25,121,243
|
|
$
|
26,579,990
|
|
Gerlach Geothermal LLC
On April 28,
2008, the Company
formed Gerlach Geothermal, LLC (Gerlach) with our
partner,
Gerlach Green Energy, LLC (GGE). The purpose of the joint
venture is the exploration of the Gerlach geothermal system, which is located in
northwestern Nevada, near the town of Gerlach. Based upon the terms of the
members agreement, the Company owned a 60% interest and GGE owned a 40%
interest in Gerlach Geothermal, LLC. The agreement gives GGE an option to
maintain its 40% ownership interest as additional capital contributions are
required. If GGE dilutes to below a 10% interest, their ownership position in
the joint venture would be converted to a 10% net profits interest. Initially,
the Company contributed $757,190 in cash and $300,000 for a geothermal lease and
mineral rights, and GGE contributed $704,460 of geothermal lease, mineral rights
and exploration data. From November 18, 2014 to March 31, 2017 the Company has
contributed $527,042 for the projects drilling costs and other costs that were
not proportionally matched by GGE. These contributions effectively increased the
Companys ownership interest to 69.15% and 68.99% at March 31, 2017 and December
31, 2016; respectively.
The consolidated financial statements reflect 100% of the
assets and liabilities of Gerlach, and report the current non-controlling
interest of GGE. The full results of Gerlachs operations are reflected in the
statement of income and comprehensive income with the elimination of the
non-controlling interest identified.
Oregon USG Holdings LLC
In September
2010, the Companys subsidiary, Oregon USG Holdings LLC (Oregon Holdings),
signed an Operating Agreement with Enbridge Inc. (Enbridge) for the right to
participate in the Companys Neal Hot Springs project located in Malheur County,
Oregon. On February 20, 2014, a new determination under the existing agreement
was reached with Enbridge that established their ownership interest percentage
at 40% and the Companys at 60%, effective January 1, 2013. Oregon Holdings has
a 100% ownership interest in USG Oregon LLC. Enbridge has contributed a total of
$32,801,000, including the debt conversion, to Oregon Holdings in exchange for a
direct ownership interest. During the three months ended March 31, 2017 and the
year ended December 31, 2016, distributions were made to the Company that
totaled $3,482,015 and $6,107,217; respectively. During the three months ended
March 31, 2017 and the year ended December 31, 2016, distributions were made to
Enbridge that totaled $2,321,343 and $4,071,478; respectively.
The consolidated financial statements reflect 100% of the
assets and liabilities of Oregon Holdings and USG Oregon LLC, and report the
current non-controlling interest of Enbridge. The full results of Oregon
Holdings and USG Oregon LLCs operations are reflected in the statement of
income and comprehensive income with the elimination of the non-controlling
interest identified.
-22-
Raft River Energy I LLC (RREI)
RREI is a
joint venture between the Company and The Goldman Sachs Group. An Operating
Agreement governs the rights and responsibilities of both parties. At December
31, 2016, the Company had contributed approximately $17.9 million in cash and
property, and Goldman Sachs has contributed approximately $34.1 million in cash.
Profits and losses are allocated to the members based upon contractual terms.
The initial contracted terms stated that the Company would be allocated 70% of
energy credit sales and 1% of the residual income/loss excluding energy credit
sales. Under the terms of the amended operating agreement that became effective
December 16, 2015, the Company will receive a 95% interest in RREIs cash flows.
Under the terms of both agreements, Goldman Sachs receives a greater proportion
of the share of profit or losses for income tax purposes/benefits. This includes
the allocation of profits and losses as well as production tax credits, which
will be distributed 99% to Goldman Sachs and 1% to the Company during the first
10 years of production, which ends December 31, 2017. No distributions were made
for the three months ended March 31, 2017. During the year ended December 31,
2016, RREI distributed funds to the Company and Goldman Sachs of $1,203,349 and
$82,473; respectively. During the three months ended March 31, 2017 and the year
ended December 31, 2016, the Company made contributions of $260,525 and
$3,349,087; respectively.
Under the terms of the December 16, 2015 agreement, the Company
is entitled to incremental profits earned as a result of additional
contributions made by the Company. During the three months ended March 31, 2017,
a new production well that was contributed to the project by the Company
produced incremental net profits of $22,471.
The consolidated financial statements reflect 100% of the
assets and liabilities of RREI, and report the current non-controlling interest
of Goldman Sachs. The full results of RREIs operations are reflected in the
statement of income and comprehensive income with the elimination of the
non-controlling interest identified.
NOTE 12 ASSET RETIRMENT OBLIGATIONS
The Geysers, California
On April 22, 2014, the
Company completed the acquisition of a group of companies owned by Ram Power
Corp.s (Ram) Geysers Project located in Northern California. Two of the
acquired companies (Western GeoPower, Inc. and Etoile Holdings, Inc.) contained
asset retirement obligations that, primarily, originate with the environmental
regulations defined by the laws of the State of California. The liabilities
related to the removal and disposal of arsenic impacted soil and existing steam
conveyance pipelines are estimated to total $598,930. Obligations related to
decommissioning four existing wells were estimated at $606,000. These
obligations are initially estimated based upon discounted cash flows estimates
and are accreted to full value over time. At March 31, 2017, the Company has not
considered it necessary to specifically fund these obligations. Since the
Company is still evaluating the development plan for this project that could
eliminate or significantly reduce the remaining obligations, no charges directly
associated the asset retirement obligations have been charged to operations. The
obligation balances at March 31, 2017 and December 31, 2016 totaled $1,219,903.
All of the obligations were considered to be long-term at March 31, 2017.
Raft River Energy I LLC, USG Nevada LLC, and USG Oregon
LLC
These Companies operate in Idaho, Nevada and Oregon and
are subject to environmental laws and regulations of these states. The plants,
wells, pipelines and transmission lines are expected to have long useful lives.
Generally, these assets will require funds for retirement or reclamation.
However, these estimated obligations are believed to be less than or not
significantly more than the assets estimated salvage values. Therefore, as of
March 31, 2017 and December 31, 2016, no retirement obligations have been
recognized.
-23-
NOTE 13 BUSINESS SEGMENTS
The Company has two reportable segments: Operating Plants, and
Corporate and Development. These segments are managed and reported separately
due to dissimilar economic characteristics. Operating plants are engaged in the
sale of electricity from the power plants pursuant to long-tern PPAs. Corporate
and development costs are intended to produce additional revenue generating
projects. A summary of financial information concerning the Companys reportable
segments is shown in the following table:
|
|
|
Operating
|
|
|
Corporate &
|
|
|
|
|
|
|
|
Plants
|
|
|
Development
|
|
|
Consolidated
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets:
|
|
|
|
|
|
|
|
|
|
|
March 31, 2017
|
|
$
|
184,028,504
|
|
$
|
56,471,344
|
|
$
|
240,499,848
|
|
December 31, 2016
|
|
|
188,682,162
|
|
|
54,742,170
|
|
|
243,424,332
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three Months Ended
March 31,
|
|
|
|
|
|
|
|
|
|
|
2017:
|
|
|
|
|
|
|
|
|
|
|
Operating Revenues
|
|
$
|
8,437,069
|
|
$
|
-
|
|
$
|
8,437,069
|
|
Net
Income (Loss)
|
|
|
2,825,886
|
|
|
(1,702,400
|
)
|
|
1,123,486
|
|
2016:
|
|
|
|
|
|
|
|
|
|
|
Operating Revenues
|
|
|
8,503,276
|
|
|
-
|
|
|
8,503,276
|
|
Net Income (Loss)
|
|
|
3,493,691
|
|
|
(2,305,896
|
)
|
|
1,187,795
|
|
-24-
Item 2 - Managements Discussion and Analysis of
Financial Condition and Results of Operations
INFORMATION REGARDING FORWARD LOOKING STATEMENTS
This document contains forward-looking statements within the
meaning of the Private Securities Litigation Reform Act of 1995. These
forward-looking statements involve a number of risks and uncertainties. We
caution readers that any forward-looking statement is not a guarantee of future
performance and that actual results could differ materially from those contained
in the forward-looking statement. These statements are based on current
expectations of future events. You can find many of these statements by looking
for words like believes, expects, anticipates, intend, estimates,
may, should, will, could, plan, predict, potential, or similar
expressions in this document or in documents incorporated by reference in this
document. Examples of these forward-looking statements include, but are not
limited to:
-
our business and growth strategies;
-
our future results of operations;
-
anticipated trends in our business;
-
the capacity and utilization of our geothermal resources;
-
our ability to successfully and economically explore for and develop
geothermal resources;
-
our exploration and development prospects, projects and programs, including
timing and cost of construction of new projects and expansion of existing
projects;
-
the fulfillment of the respective parties rights and obligations under our
joint ventures, leases, permits and all other agreements;
-
availability and costs of drilling rigs and field services;
-
our liquidity and ability to finance our exploration and development
activities;
-
our working capital requirements and availability;
-
our illustrative plant economics;
-
our illustrative growth goals and development and acquisition projections;
-
market conditions in the geothermal energy industry; and
-
the impact of environmental and other governmental regulation.
These forward-looking statements are based on the current
beliefs and expectations of our management and are subject to significant risks
and uncertainties. If underlying assumptions prove inaccurate or unknown risks
or uncertainties materialize, actual results may differ materially from current
expectations and projections. The following factors, among others, could cause
actual results to differ from those set forth in the forward-looking
statements:
-
the failure to obtain sufficient capital resources to fund our operations;
-
unsuccessful construction and expansion activities, including delays or
cancellations;
-
incorrect estimates of required capital expenditures;
-
increases in the cost of drilling and completion, or other costs of
production and operations;
-
ability to obtain a power purchase agreement for a new project;
-
the enforceability of the power purchase agreements for our projects;
-25-
-
impact of environmental and other governmental regulation, including delays
in obtaining permits or ongoing impacts of the sequester;
-
hazardous and risky operations relating to the development of geothermal
energy;
-
our ability to successfully identify and integrate acquisitions;
-
the failure of the geothermal resource to support the anticipated power
capacity;
-
our dependence on key personnel;
-
changes in applicable laws, rules or regulations;
-
the potential for claims arising from geothermal plant operations;
-
general competitive conditions within the geothermal energy industry; and
-
financial market conditions.
All subsequent written or oral forward-looking statements
attributable to us or any person acting on our behalf are expressly qualified in
their entirety by the cautionary statements contained or referred to in this
section. We do not undertake any obligation to release publicly any revisions to
these forward-looking statements to reflect events or circumstances after the
date of this document or to reflect the occurrence of unanticipated events,
except as may be required under applicable U.S. securities law. If we do update
one or more forward-looking statements, no inference should be drawn that we
will make additional updates with respect to those or other forward-looking
statements.
The U.S. dollar is the Companys functional currency. All
references to dollars or $ are to United States dollars.
General Background and Discussion
The following discussion should be read in conjunction with our
unaudited consolidated financial statements for the three months ended March 31,
2017 and notes thereto included in this quarterly report and our Annual Report
for the year ended December 31, 2016 filed with the SEC on March 9, 2017.
The Company is a Delaware corporation. The Companys common
stock trades on the NYSE MKT LLC under the trade symbol HTM.
For the quarter ended March 31, 2017, the Company was focused
on:
-
operating and optimizing the Neal Hot Springs, San Emidio and Raft River
power plants;
-
placing well RRG-5 into production at the Raft River project;
-
submitting a power plant development permit to the Bureau of Land
Management (BLM) for San Emidio Phase II;
-
preparing to deepen three additional temperature gradient wells at San
Emidio II;
-
beginning the advanced resource evaluation portion of the $1.5 million
SubTER grant from the Department of Energy at San Emidio and Crescent Valley;
-
receiving final turbine and generator bids from vendors, continuing to
optimize the power plant/hybrid cooling design, and pursuing PPA opportunities
for the WGP Geysers project;
-
received a $150,000 Small Business Voucher grant to evaluate the
installation of an integrated solar topping cycle at the Raft River project;
-
drilling a fourth water well at Neal Hot Springs; and
-
evaluating potential new geothermal projects and acquisition
opportunities.
-26-
Project Overview
The following is a list of projects that are in operation,
under development or under exploration. Projects in operation currently have
producing geothermal power plants. Projects under development have a geothermal
resource discovery or may have wells in place, but require the drilling of new
or additional production and injection wells in order to supply enough
geothermal fluid sufficient to operate a commercial power plant. Projects under
exploration do not have a geothermal resource discovery occurrence yet, but have
significant thermal and other physical evidence that warrants the expenditure of
capital in search of the discovery of a geothermal resource. Due to inflation
and marketplace increases in the costs of labor and construction materials,
estimates provided for project development costs could understate actual
costs.
Projects in Operation
Projects in Operation
|
|
|
|
|
|
|
Generating
|
|
|
|
Contract
|
Project
|
|
Location
|
|
Ownership
|
|
Capacity (megawatts)
|
|
Power Purchaser
|
|
Expiration
|
Neal Hot Springs
|
|
Oregon
|
|
JV
(1)
|
|
22.0
|
|
Idaho Power
|
|
2036
|
San Emidio (Unit I)
|
|
Nevada
|
|
100%
|
|
10.0
|
|
Sierra Pacific
|
|
2038
|
Raft River (Unit I)
|
|
Idaho
|
|
JV
(2)
|
|
13.0
(3)
|
|
Idaho Power
|
|
2032
|
|
(1)
|
The Companys equity interest in the project is 60% and
Enbridges equity interest is 40%.
|
|
(2)
|
The Companys membership interest in the project is 95%
and Goldman Sachs membership interest is 5% as the tax equity
partner.
|
|
(3)
|
The annual average net output design for the plant is 13
megawatts. The current average net output of the Raft River Unit I plant
is approximately 10.1 megawatts.
|
Facility Generation
Generation from all facilities
totaled 89,613 megawatt hours for the first quarter of 2017. For the same period
in 2016, the total generation was 93,788 megawatt hours.
Neal Hot Springs, Oregon
Neal Hot Springs is located
in Eastern Oregon near the town of Vale, the county seat of Malheur County, and
achieved commercial operation on November 16, 2012. The Neal Hot Springs
facility is designed as a 22 megawatt net annual average power plant, consisting
of three separate 12.2 megawatt (gross) modules, with each module having a
design output of 7.33 megawatts (net) annual average based on a specific flow
and temperature of geothermal brine.
For the first quarter of 2017, generation was 48,178
megawatt-hours with an average of 17.6 net megawatts per hour of operation and
plant availability was 82.5%. For the same period in 2016, the plant generated
53,671 megawatt-hours with an average of 25.4 net megawatts per hour and plant
availability was 96.7%.
On January 5, 2017 the entire facility tripped off line during
extreme cold weather conditions, and due to weather caused delays to restart the
facility, vaporizer tubes in Unit 1 froze and split, resulting in loss of
refrigerant charge and brine incursion into the refrigerant system. 80 tubes in
the vaporizers were found to have either failed or were badly damaged. All of
these tubes were plugged, and the unit was restarted on February 12, 2017, and
is operating at slightly reduced generation.
Our Property Loss insurance covers the reimbursement of all
equipment repair costs, including lost refrigerant, with a deductible level of
$50,000. A first insurance claim of $1,024,966 was made to the insurance company
and an initial payment of $1,050,000 was received on the claim. A second request
for payment of $977,204 was made to the insurance company on March 12, 2017, but
has not been received to date. The remainder of the repair costs will be totaled and
submitted to the insurance company after Unit I has gone through its annual
maintenance outage in the second quarter, and all of the damaged tubes have been
replaced.
-27-
Our Business Interruption insurance covers all lost generation,
with a 30 day deductible level. The estimated lost generation revenue for the
first 30 days of the outage was approximately $833,000. The lost generation
revenue after the 30 day deductible period, to the end of the first quarter, is
estimated at $325,406. While Unit I has been returned to service, it continues
to operate at a reduced output until the damaged tube replacements are able to
be manufactured and installed in early May. This additional lost generation will
be included in our business interruption insurance claim.
During the first quarter, a significant amount of additional
reprogramming and component tuning on all of the three generation units has been
accomplished to insure that a similar freezing event will not reoccur in the
future.
A third water supply well for the project was drilled in
December 2016, but due to extreme winter weather, was not completed until the
first quarter. While several small water zones were found, due to multiple
sloughing zones in the well, it was abandoned. A fourth well was drilled at a
different location and found an estimated 80 gallons per minute (gpm) of
water, bringing the total amount of water available from two wells to 250 gpm,
enough for one unit to be converted to hybrid cooling. Discussions are underway
to lease or purchase private surface water rights in the area. The option of
treating geothermal brine is still being investigated with a brine treatment
system operating at the site that is successfully producing high quality water
that could be used in the hybrid system if other water sources are not
identified.
Subsequent to the end of the quarter, Neal Hot Springs Unit 3
completed its annual maintenance outage from April 24 to April 28, 2017.
The PPA for the project was signed on December 11, 2009 with
the Idaho Power Company. It has a 25-year term, and a variable percentage annual
price escalation. The PPA has a seasonal pricing structure that pays 120% of the
average price for four months (July, August, November, December), 100% of the
average price for five months (January, February, June, September, October) and
73.3% of the average price for three months (March, April, May). The annual
average price paid under the PPA for 2017 is $111.83 ($109.27 for 2016) per
megawatt-hour.
San Emidio Unit I, Nevada
The Unit I power plant at
San Emidio is located approximately 100 miles north-east of Reno, Nevada near
the town of Gerlach, and achieved commercial operation on May 25, 2012. The San
Emidio facility is a single 14.7 megawatt (gross) module, with a design output
of 9 megawatts (net) annual average based on a specific flow and temperature of
geothermal brine.
For the first quarter of 2017, generation was 19,501
megawatt-hours with an average of 9.2 net megawatts per hour of operation and
plant availability was 98.6%. For the same period in 2016, the plant generated
20,433 megawatt-hours with an average of 9.4 net megawatts per hour and plant
availability was 99.4%. The reduced generation was caused by the submersible
pump motor in production well 61-21 failing on January 12, 2017. A standby
production well with lower temperature was placed in service, which reduced the
amount of lost generation. A new motor, which was provided by the manufacturer
under warranty, and rebuilt pump were installed, and well 61-21 resumed
production on March 3, 2017. Subsequent to the end of the quarter, San Emidio
completed its annual maintenance outage from April 2 to April 10, 2017.
On June 1, 2011, an amended and restated PPA was signed with
Sierra Pacific Power Company d/b/a NV Energy for the sale of up to 19.9
megawatts of electricity on an annual average basis from two units. The option for the second unit expired in December 2015. The PPA
has a 25-year term with a base price of $89.75 per megawatt-hour, and an annual
escalation rate of 1 percent. The annual average price paid under the PPA for
2017 is $93.94 ($93.01 for 2016) per megawatt-hour.
-28-
Raft River, Idaho
Raft River Energy I (RREI) is
located in Southern Idaho, near the town of Malta, and achieved commercial
operation on January 3, 2008. The Raft River facility is a single 18 megawatt
(gross) module, with a design output of 13 megawatts (net) annual average based
on a specific flow and temperature of geothermal brine.
For the first quarter of 2017, generation was 21,934
megawatt-hours with an average of 10.1 net megawatts per hour of operation and
plant availability was 100%. For the same period in 2016, the plant generated
19,684 megawatt-hours with an average of 9.4 net megawatt hours and plant
availability was 100.0%. The increased generation in 2017 is primarily due to
having all production wells on-line compared to 2016 when production well RRG-2
failed in February 2016 and was off line for the remainder of the first
quarter.
Well RRG-5, an idle injection well with significant
permeability, was converted to production with piping modifications and the
installation of a pump and, commenced operation on March 21, 2017. It is
currently operating at the flow rate of 1,100 gpm, with a temperature of just
over 247°F. The increased flow to the plant is generating an additional 0.71
megawatts per hour. To date, the reservoir response has been significantly
better than projected, with minimal drawdown in well RRG-5 and no impact to
water level in the adjoining wells.
The next step to optimize output from the wellfield is to
increase the capacity of the injection system by upgrading an injection pump. A
further increase in fluid flow to the plant is expected during the third quarter
after the injection pump upgrade is completed, which will result in a further
increase in generation. The targeted increase for this phase of the program is
1.5 to 2 megawatts, which depends in part on the final temperature that well
RRG-5 achieves. Once the upgraded injection pump is in service and the wellfield
is rebalanced to maximize output, additional changes will be analyzed to further
increase the generation level of the plant. The Raft River PPA allows for 13
megawatts of generation.
Well RRG-9, which has been used as part of an $11.4 million
thermal stimulation grant funded primarily by the DOE, has continued to increase
in injection capacity to a current level of 1,360 gpm. This injection capacity
is sufficient to provide all of the additional volume needed to accept the flow
from well RRG-5 without requiring any new drilling.
Subsequent to the end of the quarter, we were awarded a
$150,000 Small Business Voucher grant to evaluate the installation of an
integrated solar topping turbine at the Raft River project. The total cost of
the program is $187,500, with the Company providing $37,500 in cost share. Two
DOE national laboratories are working on the solar topping design with the
Company; the National Renewable Energy Laboratory (NREL), operated by the
Alliance for Sustainable Energy, LLC, and Idaho National Laboratory (INL), which
performs work in each of DOEs strategic goal areas: energy, national security,
science and environment, and is operated by Battelle Energy Alliance.
The PPA for the project was signed on September 24, 2007 with
the Idaho Power Company and allows for the sale of up to 13 megawatts of
electricity on an annual average basis. The PPA has a 25 year term with a
starting average price for the year 2007 of $52.50 that escalates at 2.1% per
year through 2020 and then at 0.6% per year until the end of the contract in
2034. The Idaho Power PPA has a seasonal pricing structure that pays 120% of the
average price for four months (July, August, November, December), 100% of the
average price for five months (January, February, June, September, October) and
73.5% of the average price for three months (March, April, May). The annual
average price paid under the PPA for 2017 is $64.63 ($63.00 for 2016) per
megawatt-hour.
-29-
In addition to the price paid for energy by Idaho Power, Raft
River Unit I currently receives $4.75 per megawatt-hour under a separate
contract for the sale of RECs to Holy Cross Energy, a Colorado electric
cooperative. Starting in calendar year 2018, 51% of the RECs produced by the
project will be owned by the Idaho Power Company and 49% by the project. For the
49% of RECs owned by the Raft River project, a new, 10 year REC contract with
the Public Utility District No. 1 of Clallam County, Washington will replace the
current contract, also in 2018.
Projects Under Development/Exploration
Projects Under Development
|
|
|
|
|
|
Estimated
|
|
|
|
|
Target
|
Projected
|
Capital
|
|
|
|
|
Development
|
Commercial
|
Required
|
Power
|
Project
|
Location
|
Ownership
|
(Megawatts)
|
Operation Date
|
($million)
|
Purchaser
|
Raft River
|
Idaho
|
100%
|
1-3
|
3
rd
Quarter 2017
|
4
|
IDPC
|
Neal Hot Springs
|
Oregon
|
60%
|
3
|
4
th
Quarter 2017
|
10
|
IDPC
|
San Emidio Phase II
|
Nevada
|
100%
|
35-45
|
4
th
Quarter 2019*
|
145
|
TBD
|
WGP Geysers
|
California
|
100%
|
30
|
4
th
Quarter 2018*
|
150
|
TBD
|
El Ceibillo Phase I
|
Guatemala
|
100%
|
25
|
2
nd
Quarter 2019*
|
140
|
TBD
|
Crescent Valley Phase I
|
Nevada
|
100%
|
25
|
2
nd
Quarter 2020*
|
130
|
TBD
|
|
* - Commercial operation dates are projections only.
Actual dates can only be provided after power purchase agreements have
been obtained.
|
|
Properties Under Exploration
|
|
|
|
|
|
|
Target Development
|
Project
|
|
Location
|
|
Ownership
|
|
*(Megawatts)
|
Gerlach
|
|
Nevada
|
|
67.4%
|
|
10
|
Vale
|
|
Oregon
|
|
100%
|
|
15
|
El Ceibillo Phase II
|
|
Guatemala
|
|
100%
|
|
25
|
Neal Hot Springs II
|
|
Oregon
|
|
100%
|
|
10
|
Raft River Phase II
|
|
Idaho
|
|
100%
|
|
13
|
Crescent Valley Phase II
|
|
Nevada
|
|
100%
|
|
25
|
Crescent Valley Phase III
|
|
Nevada
|
|
100%
|
|
25
|
Lee Hot Springs
|
|
Nevada
|
|
100%
|
|
20
|
Ruby Hot Springs Phase I
|
|
Nevada
|
|
100%
|
|
20
|
|
* - Target development sizes are predevelopment estimates
of resource potential of unproven resources. The estimates are based on
our evaluation of available information regarding temperature, and where
available, flow.
|
|
WGP Geysers, California
The WGP Geysers project is
located in the broader Geysers geothermal field located approximately 75 miles
north of San Francisco, California. The broader Geysers geothermal field is the
largest producing geothermal field in the world generating more than 850
megawatts of power for more than 30 years. Acquisition of the WGP Geysers
Project from Ram Power was completed on April 22, 2014 for $6.4 million. We
expect that approximately 75% of the development may be funded by non-recourse
project debt, with the remainder funded through equity financing. We anticipate
the project qualifying for the 30% Federal Investment Tax Credit, which when
monetized can meet most of the equity financing requirements.
-30-
Engineering optimization of the new, hybrid power plant design
has been completed and final quotes for the turbine-generator have been
received. Our engineers and consultants are working in concert with our EPC
contractors to examine all aspects of the construction cycle with a focus
further on reducing construction costs. The hybrid design will dramatically
increase the volume of water available for injection back into the reservoir,
which will result in increased power generation over the life of the project.
Traditional water cooled geothermal steam plants re-inject approximately 20 to
25% of the water that is extracted from the steam, while our current hybrid
design may re-inject approximately 80% more of the water. This higher injection
rate will provide long term, stable steam production, and will result in
increased power generation over the life of the project.
The Conditional Use Permit from Sonoma County, which approves
the construction plan for the WGP Geysers power plant, was received on December
16, 2016. Combined with the Large Generator Interconnection Agreement that was
received from the California Independent System Operator and Pacific Gas &
Electric, this completes the long lead permits and agreements that are needed
for the project. Once final engineering design is finished, and a PPA is
executed, an air quality permit and building permit will be needed before on
site construction will begin.
We received the signed Large Generator Interconnection
Agreement for the project on March 6, 2016 with the California Independent
System Operator and Pacific Gas & Electric (PG&E). This agreement allows
the project to connect to the transmission grid and deliver up to 35 megawatts
of energy. The Company has paid the total interconnection cost of $1.9 million
for the grid operators portion of the work in the substation. An additional 1.7
mile long transmission line will be required to connect from the plant to the
substation and discussions are underway with the landowners to acquire a
right-of-way.
Based on flow test data generated from well flow testing
performed in mid-2015, a third party expert reported in September 2015, that the
four production wells already drilled are capable of delivering an initial
capacity of 28.1 MW (gross) or 25.4 MW (net) based on current power plant steam
conversion rates from a detailed design for a 28.8 MW (net) power plant. These
tests show the wells would initially produce a combined total of 458,000 pounds
per hour. Using the average steam production rate from these wells and an
assumed interference factor of 30%, the third party expert estimates that an
additional two to three production wells would be needed to support the
long-term operation of a 28.8 MW (net) plant. Using the large data base from the
surrounding Geysers geothermal field, the historic WGP well production data, and
the 2015 flow test information, a numerical reservoir model is being prepared to
provide the final well requirements and targeting for injection sites.
Discussions are being held with several potential California
based power purchasers for the generation from the WGP Geysers plant. The
potential power purchasers have expressed interest in renewable, base load
power, to replace fossil fuel based power generation that is being phased out of
some of their portfolios and to stabilize and balance intermittent resources
already in their portfolios. A number of community choice aggregators are also
expected to issue Requests for Proposals for the purchase of renewable energy
during 2017. Bilateral negotiations are continuing with a potential offtaker
that had shortlisted our bid in their 2016 solicitation.
El Ceibillo, Republic of Guatemala
A geothermal
energy rights concession, located 14 kilometers southwest of Guatemala City, was
awarded to U.S. Geothermal Guatemala S.A., a wholly owned subsidiary of the
Company in April 2010. The concession agreement contains a schedule that
requires the development and construction of a power plant. In July 2015, the
Guatemalan Ministry of Energy and Mines approved a modified construction
schedule that extended the development and construction period to June 1, 2018.
There are 24,710 acres (100 square kilometers) in the concession, which is at
the center of the Aqua and Pacaya twin volcano complex.
-31-
Production well EC-5 was completed to a depth of 1,450 feet
(442 meters) on August 20, 2016 and intersected a high permeability zone at
1,299 feet (396 meters). EC-5 underwent a series of flow tests, with field wide
monitoring, beginning on September 5, 2016 and ran until September 13, 2016.
Data was collected from three monitoring wells during the test (EC-2A, EC-3, and
EC-4) to provide pressure data for the reservoir model. Fluid samples taken at
the end of the flow test indicate a potential reservoir temperature of 450 to
523°F (232 to 273°C).
With the shallow, commercial resource now indicated, a deep
well is planned in 2017 to test the producing structure down dip from well EC-5
to a projected depth of 1,970 to 2,300 feet (600-800 meters). A deeper
intersection in the reservoir could increase the reservoir capacity and
production temperature and change the design of the power plant. Well EC-1,
which was drilled in 2013 to a depth of 5,650 feet (1,722 meters) found a
measured bottom-hole temperature of 526°F (274°C), but did not intersect
permeability. The comparative geology between EC-5 and EC-1 suggests a fault or
other structure feeding the reservoir may be located in the area between the two
wells. A site has been constructed to drill well EC-6 to test this area.
On January 10, 2017, the Guatemalan government, through the
National Electrical Energy Commission (COMISIÓN NACIONAL DE ENERG¥A
ELÉCTRICACNEE),
announced that it is preparing to issue an RFP later
this year for 420 megawatts of power, of which 40 megawatts is to be reserved
specifically for geothermal energy. When the RFP is issued, the El Ceibillo
project will be bid into the process.
San Emidio Phase II, Nevada
The Phase II expansion
is dependent on successful development of additional production and injection
well capacity. We expect that approximately 75% of the Phase II development may
be funded by non-recourse project debt, with the remainder funded through equity
financing. We anticipate the project qualifying for the 30% Federal Investment
Tax Credit (or Production Tax Credit), which when monetized, can meet most of
the equity financing requirements.
A power plant development permit application for the San Emidio
Phase II project was submitted to the BLM on March 29, 2017. The application
provides for the installation of three power plant units, up to 20 wells, and
the transmission line needed to develop the project. It is expected that the
evaluation by the BLM will take 12 months or longer to complete. Additional
cultural and threatened & endangered species surveys will be undertaken
during 2017 in support of the permit. Permits to deepen three temperature
gradient wells were received from the BLM in December 2016. Drilling will begin
as soon as weather permits access to the well pads. These three wells will be
deepened to the expected reservoir depth of 1,800 to 2,500 feet deep, to further
explore the Southwest Zone. If the wells are successful, the length of the
productive reservoir could be extended by 1,000 feet.
The updated reservoir model (announced January 11, 2017)
resulted in a significant increase in the potential size of the San Emidio Phase
II reservoir of up to 47 net megawatts. Data from flow tests that took place in
late 2016 from two observation wells were incorporated into a Probabilistic
Power Density model, which estimates the net generation potential of a
reservoir. Based on the flow rate and temperature produced by the two
observation wells, and by measurement of pressure response both in the wells and
across the wellfield, the model estimates that the Most Likely Outcome (50%
probability) is 47 net megawatts of generation capacity within a 1.4 square mile
area. The Minimum level of generation capacity (90% probability) occurs in a
0.18 square mile area, and has 18.8 net megawatts of generation capacity.
These two observation wells are approximately 1,700 feet apart,
along the new structural trend identified in the Southwest Zone, which is still
open for expansion. Temperature gradient well data and seismic information
indicate a potential strike length for the Southwest Zone of up to 2,700 feet.
This compares to a strike length for the primary producing wellfield at San
Emidio Phase I of 800 feet, which supports the potential for the larger
estimated resource in this Southwest Zone.
-32-
The three power plant units that were previously purchased in
2016 are available to provide this project with the major, long lead equipment
requirements for 35-45 net megawatts of power (depending upon cooling system
used). The increased San Emidio II reservoir capacity with a 320°F+ temperature
fits the design range of the equipment. These new, unused components represent
approximately 70% of the equipment needed for a complete facility similar to the
Companys Neal Hot Springs operation.
Given the larger estimated resource capacity at San Emidio II,
we have cancelled our Small Generator Interconnection Agreement with NV Energy
that was completed in 2016 and are preparing to apply for a Large Generator
Interconnection Agreement with a 45 megawatt capacity in support of the higher
expected output. Additionally, transmission studies by an outside engineering
firm that include the potential for power sales into Southern California are
underway.
In July 2016, the Company was awarded a $1.5 million DOE cost
share grant under the Development of Technologies for Sensing, Analyzing, and
Utilizing Novel Subsurface Signals in Support of the Subsurface Technology and
Engineering (SubTER) Crosscut Initiative. The program approved under the
grant includes using new subsurface technologies at both San Emidio and Crescent
Valley to identify fluid flow paths in the geothermal resource. The data
collection phase of the program was completed at San Emidio in December. The
data is being interpreted to determine whether viable targets have been
identified. Upon approval from the DOE, a second phase of the grant program is
designed to confirm the findings by drilling. The total program cost is $1.9
million with the Company providing $400,000 in cost share.
Raft River Phase II, Idaho
In 2011, the Raft River
Phase II project was awarded an $11.4 million cost-shared, thermal stimulation
program grant from the DOE with the University of Utah Energy And Geoscience
Institute as the project lead. The goal of the project is to create an Enhanced
Geothermal System (EGS) by creating thermal fractures and developing a
corresponding increase in permeability in the low permeability rock. Well RRG-9
was made available for the program and the first stage of injection into the
well began in June 2013.
Initially the well was only capable of receiving 20 gpm of
water due to the low permeability of the rock. After several moderate pressure
stimulations, the injection of cold power plant discharge fluid was started and
has continued to date. The lower temperature fluid causes thermal fracturing
within the higher temperature host rock of the reservoir. At the current plant
generation level, the flow into the well has continued to increase and is now
approximately 1,360 gpm.
Well RRG-9 continues to be used temporarily as an injection
well as an extension of the DOE EGS program, which is expected at this time to
continue through until mid-2017. The Companys contributions for the thermal
stimulation program are made in-kind by the use of the RRG-9 well, well field
data provided by the Company, and through ongoing labor for monitoring support.
Crescent Valley, Nevada
The Crescent Valley prospect
consists of approximately 21,300 acres (33.3 square miles) of private and
Federal geothermal leases. It is located in Eureka County, Nevada, approximately
15 miles south of the Beowawe geothermal power plant and about 33 miles
southeast of Battle Mountain. The project was acquired as part of the Earth
Power Resources merger which was completed in December 2014.
In light of federal legislation that extended the qualification
for the 30% Federal Investment Tax Credit to projects that began construction
prior to December 31, 2014, drilling of the first production/injection well
CVP-001 (67-3) was initiated in December of 2014, following completion of
gravity surveys, and analysis of prior temperature gradient drilling data. Well
CVP-001 was completed on March 27, 2015 to a depth of 2,746 feet. The well
exhibited modest permeability with a flowing temperature of 213°F, which makes
the well suited for duty as an injection well.
-33-
The SubTER program, approved under the DOE grant awarded in
July 2016, includes using new subsurface technologies at both San Emidio and
Crescent Valley to identify fluid flow paths in the geothermal resource. The
passive seismic data collection phase of the program was completed at Crescent
Valley in December of 2016. The data is being interpreted to develop a 3D map to
help identify future drilling targets. The details of this award are discussed
in the San Emidio Phase II project discussion above.
Operating Results
For the three months ended March 31, 2017, the Company reported
net income attributable to the Company of $260,890 ($0.01 income per share)
which represented an increase of $109,498 (72.3% increase) from net income
attributable to the Company of $151,392 ($0.01 income per share) reported in the
same period ended 2016. Both favorable and unfavorable variances were reported
in areas related to the operations of the Companys three power plants. Notable
favorable variances were reported for professional fees and promotion expenses.
A notable unfavorable variances were noted for interest expense and income tax
expense.
Plant Operations
A summary of energy sales by plant location is as follows:
|
|
For
the Three Months Ended March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%
|
|
Neal Hot Springs, Oregon
|
|
5,210,556
|
|
|
62.5
|
|
|
5,366,004
|
|
|
63.8
|
|
San Emidio, Nevada
|
|
1,831,890
|
|
|
22.0
|
|
|
1,900,467
|
|
|
22.6
|
|
Raft River, Idaho
|
|
1,292,004
|
|
|
15.5
|
|
|
1,144,351
|
|
|
13.6
|
|
|
|
8,334,450
|
|
|
100.0
|
|
|
8,410,822
|
|
|
100.0
|
|
%
- represents the percentage of total Company energy
sales
.
A quarterly summary of megawatt hours generated by plant are as
follows:
|
|
For
the Quarter Ended,
|
|
|
|
March 31,
|
|
|
June 30,
|
|
|
September 30,
|
|
|
December 31,
|
|
|
March 31,
|
|
|
|
2016
|
|
|
016
|
|
|
2016
|
|
|
2016
|
|
|
2017
|
|
Neal Hot Springs, Oregon
|
|
53,671
|
|
|
39,094
|
|
|
29,758
|
|
|
57,036
|
|
|
48,178
|
|
San Emidio, Nevada
|
|
20,433
|
|
|
14,139
|
|
|
19,675
|
|
|
20,803
|
|
|
19,501
|
|
Raft River, Idaho
|
|
19,684
|
|
|
15,647
|
|
|
16,622
|
|
|
20,039
|
|
|
21,934
|
|
|
|
93,788
|
|
|
68,880
|
|
|
66,055
|
|
|
97,878
|
|
|
89,613
|
|
Neal Hot Springs, Oregon (USG Oregon LLC) Plant
Operations
For the three months ended March 31, 2017, the Neal Hot Springs
plant reported subsidiary net income of $2,345,574 which was a decrease of
$881,166 (27.3% decrease) from subsidiary net income of $3,226,740 reported in
the same period ended 2016.
Energy sales for the three months ended March 31, 2017,
decreased 2.9% from the same period ended 2016. On January 5, 2017, Unit 1
experienced mechanical failures, primarily due to extreme cold temperatures that
resulted in outages and the loss of a substantial amount of that Units
refrigerant. The Units complications resulted in a total of 1,025 lost
production hours during the current quarter. The initial repairs to identify and plug the damaged tubes were
completed on February 12, 2017; however, Unit 1 will operate at a reduced level
until the plugged heat exchanger tubes can be replaced during the annual
maintenance outage scheduled for May 2017. Business Interruption insurance,
provided $325,406 of revenue to cover lost energy sales after the first 30 days
of lost generation. Without the insurance coverage, energy sales for the current
quarter would have decreased 9.0% from the same period ended 2016.
-34-
Plant operating expenses, excluding depreciation, increased
$742,032 (80.8% increase) for the three months ended March 31, 2017 from the
same period ended 2016. The largest increases were in property taxes of
$705,193. For the first years of operations, property taxes were abated by the
County. The abatement period ended in 2016 and the first property tax payment
was made in December 2016.
Significant repair and refrigerant replacement costs totaling
estimated to be $1.7 million were required during the current quarter for Unit
1, of which the refrigerant replacement costs alone exceeded $758,000. Property
Loss insurance covered all of those costs except for a $50,000 deductible.
Summarized statements of operations for the Neal Hot Springs,
Oregon plant are as follows:
|
|
Three
Months Ended March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
Variance
|
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%*
|
|
Plant revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Energy sales
|
|
5,210,556
|
|
|
100.0
|
|
|
5,366,004
|
|
|
100.0
|
|
|
(155,448
|
)
|
|
(2.9
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Plant expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General operations
|
|
1,659,880
|
|
|
31.9
|
|
|
917,848
|
|
|
17.2
|
|
|
(742,032
|
)
|
|
(80.8
|
)
|
Depreciation and amortization
|
|
826,748
|
|
|
15.8
|
|
|
818,062
|
|
|
15.2
|
|
|
(8,686
|
)
|
|
1.1
|
|
|
|
2,486,628
|
|
|
47.7
|
|
|
1,735,910
|
|
|
32.4
|
|
|
(750,718
|
)
|
|
(43.2
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross Profit
|
|
2,723,928
|
|
|
52.3
|
|
|
3,630,094
|
|
|
67.6
|
|
|
(906,166
|
)
|
|
(25.0
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
(380,057
|
)
|
|
(7.3
|
)
|
|
(405,315
|
)
|
|
(7.5
|
)
|
|
25,258
|
|
|
6.2
|
|
Other and interest
income
|
|
1,703
|
|
|
0.0
|
|
|
1,961
|
|
|
0.0
|
|
|
(258
|
)
|
|
(13.2
|
)
|
|
|
(378,354
|
)
|
|
(7.3
|
)
|
|
(403,354
|
)
|
|
(7.5
|
)
|
|
25,000
|
|
|
(6.2
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subsidiary Net Income
|
|
2,345,574
|
|
|
45.0
|
|
|
3,226,740
|
|
|
60.1
|
|
|
(881,166
|
)
|
|
(27.3
|
)
|
%
- represents the percentage of
total plant operating revenues
.
%*
- represents the percentage
of change from 2016 to 2017
.
Increases in revenues and
decreases
in expenses from the prior period to the current period are considered favorable
and are presented as positive figures.
The intercompany elimination adjustments for interest
expense, management fees and lease costs are not incorporated into the
presentation of the subsidiarys operations.
-35-
Key quarterly production data for the Neal Hot Springs, Oregon
plant is summarized as follows:
|
|
Mega-
|
|
|
|
Ave. Rate
|
|
|
|
Depreciation
|
|
|
watt
|
|
Energy
|
|
per
|
|
Subsidiary
|
|
&
|
|
|
Hours
|
|
Sales
|
|
Megawatt
|
|
Net Income*
|
|
Amortization
|
Quarter Ended:
|
|
Produced
|
|
($)
|
|
Hour
($)
|
|
($)
|
|
($)
|
March 31, 2015
|
|
53,500
|
|
5,207,350
|
|
97.3
|
|
3,010,263
|
|
819,708
|
June 30, 2015
|
|
37,232
|
|
3,188,091
|
|
85.6
|
|
1,027,928
|
|
819,785
|
September 30, 2015
|
|
33,498
|
|
4,004,715
|
|
119.3
|
|
1,651,029
|
|
819,450
|
December 31, 2015
|
|
52,642
|
|
6,423,643
|
|
122.0
|
|
4,311,789
|
|
819,171
|
March 31, 2016
|
|
53,671
|
|
5,366,004
|
|
100.0
|
|
3,226,740
|
|
818,062
|
June 30, 2016
|
|
39,094
|
|
3,445,321
|
|
88.2
|
|
1,243,706
|
|
820,063
|
September 30, 2016
|
|
29,758
|
|
3,651,073
|
|
122.4
|
|
1,279,527
|
|
820,546
|
December 31, 2016
|
|
57,036
|
|
7,099,320
|
|
124.5
|
|
4,471,869
|
|
823,116
|
March 31, 2017
|
|
48,178
|
|
5,210,556
|
|
101.4
|
|
2,345,574
|
|
826,748
|
* - The intercompany elimination
adjustments for management fees and corporate support are not incorporated into
the presentation of the subsidiarys net income.
San Emidio, Nevada Plant Energy Sales and Plant Operating
Expenses (USG Nevada LLC)
For the three months ended March 31, 2017, the San Emidio plant
reported subsidiary net income of $425,071 which was a decrease of $376 (0.1%
decrease) from $425,447 subsidiary net income reported in the same period ended
2016.
Energy sales for the three months ended March 31, 2017,
decreased 3.6% from the same periods ended 2016. During the current three
months, the plant produced 19,501 megawatt hours, which was a 4.6% decrease from
the same periods ended 2016. During the current quarter, the plant experienced
forced outages when it tripped off-line due a pressure indicating transmitter
failure and issues with the power purchasers substations. No outages were
reported in the first quarter of 2016.
Plant operating costs, excluding depreciation, decreased
$59,252 for the three months ended March 31, 2017, which was a 9.0% decrease
from the same period ended 2016. A notable decrease in operating expenses was
related to taxes and licenses. During the first quarter 2016, the Company was
required to pay additional minerals proceeds tax for $70,747 after an
examination by the State of Nevada.
-36-
Summarized statements of operations for the San Emidio, Nevada
plant are as follows:
|
|
Three
Months Ended March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
Variance
|
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%*
|
|
Plant revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Energy sales
|
|
1,831,890
|
|
|
100.0
|
|
|
1,900,467
|
|
|
100.0
|
|
|
(68,577
|
)
|
|
(3.6
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Plant expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operations
|
|
598,796
|
|
|
32.7
|
|
|
658,048
|
|
|
34.7
|
|
|
59,252
|
|
|
9.0
|
|
Depreciation and amortization
|
|
321,051
|
|
|
17.5
|
|
|
318,214
|
|
|
16.7
|
|
|
(2,837
|
)
|
|
(0.9
|
)
|
|
|
919,847
|
|
|
50.2
|
|
|
976,262
|
|
|
51.4
|
|
|
56,415
|
|
|
5.8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross Profit
|
|
912,043
|
|
|
49.8
|
|
|
924,205
|
|
|
48.6
|
|
|
(12,162
|
)
|
|
(1.3
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
(490,076
|
)
|
|
(26.8
|
)
|
|
(500,613
|
)
|
|
(26.3
|
)
|
|
10,537
|
|
|
2.1
|
|
Other income
|
|
3,104
|
|
|
0.2
|
|
|
1,855
|
|
|
0.1
|
|
|
1,249
|
|
|
67.3
|
|
|
|
(486,972
|
)
|
|
(26.6
|
)
|
|
(498,758
|
)
|
|
(26.2
|
)
|
|
11,786
|
|
|
2.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subsidiary Net Income
|
|
425,071
|
|
|
23.2
|
|
|
425,447
|
|
|
22.4
|
|
|
(376
|
)
|
|
(0.1
|
)
|
%
- represents the percentage of
total plant operating revenues
.
%*
- represents the percentage
of change from 2016 to 2017
.
Increases in revenues and decreases
in expenses from the prior period to the current period are considered
favorable and are
presented as positive figures.
The intercompany elimination
adjustments for management fees are not incorporated into the presentation of
the subsidiarys net operating income/loss.
Key quarterly production data for the San Emidio, Nevada plant
is summarized as follows:
|
|
Mega-
|
|
|
|
Ave. Rate
|
|
Subsidiary
|
|
Depreciation
|
|
|
watt
|
|
Energy
|
|
per
|
|
Net Income
|
|
&
|
|
|
Hours
|
|
Sales
|
|
Megawatt
|
|
(Loss)*
|
|
Amortization
|
Quarter Ended:
|
|
Produced
|
|
($)
|
|
Hour
($)
|
|
($)
|
|
($)
|
March 31, 2015
|
|
21,754
|
|
2,003,346
|
|
92.1
|
|
556,301
|
|
316,346
|
June 30, 2015
|
|
18,492
|
|
1,702,633
|
|
92.1
|
|
264,410
|
|
315,846
|
September 30, 2015
|
|
18,924
|
|
1,742,750
|
|
92.1
|
|
386,033
|
|
314,940
|
December 31, 2015
|
|
20,369
|
|
1,875,755
|
|
92.1
|
|
278,453
|
|
316,269
|
March 31, 2016
|
|
20,433
|
|
1,900,467
|
|
93.0
|
|
425,447
|
|
318,214
|
June 30, 2016
|
|
14,139
|
|
1,315,049
|
|
93.0
|
|
(142,273)
|
|
319,756
|
September 30, 2016
|
|
19,675
|
|
1,829,996
|
|
93.0
|
|
384,018
|
|
321,479
|
December 31, 2016
|
|
20,803
|
|
1,934,846
|
|
93.0
|
|
375,074
|
|
321,222
|
March 31, 2017
|
|
19,501
|
|
1,831,890
|
|
93.9
|
|
425,071
|
|
321,051
|
*
-
The
intercompany elimination adjustments for management fees and corporate support
charges are not incorporated into the presentation of the subsidiarys net
income/loss.
Raft River, Idaho Unit I (Raft River Energy I LLC) Plant
Operations
For the three months ended March 31, 2017, the Raft River plant
reported subsidiary net income of $55,241 which was an increase of $213,738
(134.9% increase) from $158,497 subsidiary net loss reported in the same period
ended 2016.
-37-
Energy sales, for the three months ended March 31, 2017
increased 12.9% from the same period ended 2016. During the three months ended
March 31, 2017, the plant produced 21,934 megawatts, which was an 11.4% increase
from the same period ended 2016. In February 2016, a production well (RRG-2) was
taken off line in order to facilitate the well expansion project. This well was
reconnected to the plant when the project was completed in June 2016. On March
21, 2017, a new production well (RRG-5) was connected to the plant. The new well
addition has increased the net power production of the plant by approximately
0.71 megawatts.
Plant operating costs, excluding depreciation, decreased
$96,516 for the three months ended March 31, 2017, which was a 10.1% decrease
from the same period ended 2016. During the three months ended March 31, 2016,
costs of approximately $96,000 were incurred to pull a production pump for
repairs. Unplanned repairs were not needed in the current quarter.
The summarized statements of operations for RREI are as
follows:
|
|
Three
Months Ended March 31,
|
|
|
|
2017
|
|
|
2016
|
|
|
Variance
|
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%
|
|
|
$
|
|
|
%*
|
|
Plant revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Energy sales
|
|
1,292,004
|
|
|
92.6
|
|
|
1,144,351
|
|
|
92.5
|
|
|
147,653
|
|
|
12.9
|
|
Energy credit
sales
|
|
102,619
|
|
|
7.4
|
|
|
92,454
|
|
|
7.5
|
|
|
10,165
|
|
|
11.0
|
|
|
|
1,394,623
|
|
|
100.0
|
|
|
1,236,805
|
|
|
100.0
|
|
|
157,818
|
|
|
12.8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Plant expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General
operations
|
|
854,588
|
|
|
61.3
|
|
|
951,104
|
|
|
76.9
|
|
|
96,516
|
|
|
10.1
|
|
Depreciation and amortization
|
|
484,949
|
|
|
34.8
|
|
|
444,587
|
|
|
35.9
|
|
|
(40,362
|
)
|
|
(9.1
|
)
|
|
|
1,339,537
|
|
|
96.1
|
|
|
1,395,691
|
|
|
112.8
|
|
|
56,154
|
|
|
4.0
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross Profit (Loss)
|
|
55,086
|
|
|
3.9
|
|
|
(158,886
|
)
|
|
(12.8
|
)
|
|
213,972
|
|
|
134.7
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense)
|
|
155
|
|
|
0.0
|
|
|
389
|
|
|
0.0
|
|
|
(234
|
)
|
|
60.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subsidiary
Net
Income
(Loss)
|
|
55,241
|
|
|
3.9
|
|
|
(158,497
|
)
|
|
(12.8
|
)
|
|
213,738
|
|
|
134.9
|
|
%
- represents the percentage of
total plant operating revenues
.
%*
- represents the percentage
of change from 2016 to 2017
.
Increases in revenues and decreases
in expenses from the prior period to the current period are considered to
be favorable and
are presented as positive figures.
The intercompany elimination
adjustments for interest expense, management fees and lease costs are not
incorporated into the presentation of the subsidiarys operations.
-38-
Key quarterly production data for RREI is summarized as
follows:
|
|
Mega-
|
|
|
|
Ave. Rate
|
|
Subsidiary
|
|
Depreciation
|
|
|
watt
|
|
Energy
|
|
per
|
|
Net Income
|
|
&
|
|
|
Hours
|
|
Sales
|
|
Megawatt
|
|
(Loss)*
|
|
Amortization
|
Quarter Ended:
|
|
Produced
|
|
($)
|
|
Hour
($)
|
|
($)
|
|
($)
|
March 31, 2015
|
|
20,672
|
|
1,165,050
|
|
56.4
|
|
(96,930)
|
|
431,959
|
June 30, 2015
|
|
17,223
|
|
888,599
|
|
51.6
|
|
(668,764)
|
|
438,955
|
September 30, 2015
|
|
15,950
|
|
1,106,643
|
|
69.4
|
|
(296,743)
|
|
443,233
|
December 31, 2015
|
|
21,751
|
|
1,533,621
|
|
70.5
|
|
425,745
|
|
443,744
|
March 31, 2016
|
|
19,684
|
|
1,144,351
|
|
58.2
|
|
(158,497)
|
|
444,587
|
June 30, 2016
|
|
15,647
|
|
829,554
|
|
52.1
|
|
(321,895)
|
|
444,608
|
September 30, 2016
|
|
16,622
|
|
1,173,294
|
|
71.5
|
|
(288,634)
|
|
444,878
|
December 31, 2016
|
|
20,039
|
|
1,452,737
|
|
72.5
|
|
130,804
|
|
480,864
|
March 31, 2017
|
|
21,934
|
|
1,292,004
|
|
58.9
|
|
55,241
|
|
484,949
|
* - Subsidiary net income (loss)
does not include intercompany elimination adjustments for interest expense,
management fees and lease costs.
Professional and Management Fees
For the three
months ended March 31, 2017, the Company reported $145,765 in professional and
management fees which was a decrease of $910,744 (86.2% decrease) from
$1,056,509 reported in the same period ended 2016. During the current quarter,
the Company incurred routine professional services and fees. In August of 2015,
the Company formed a Special Committee of the Board of Directors to thoroughly
explore strategic options to maximize shareholder value. The Company ended this
process and ended the contract with the primary consultant that was engaged in
the examination in March 2016. For the first quarter 2016, the consultants fees
associated with this examination exceeded $544,000. Legal fees that exceeded
$100,000 were incurred in the first quarter of 2016 to support the examination
and issuance of common shares. The Company incurred fees of $100,000 for
services provided by a new financial advisor hired during the first quarter
2016. These consultant services were discontinued in June 2016.
Travel and Promotion
For the three months ended
March 31, 2017, the Company reported $36,835 in travel and promotional costs
which were a decrease of $46,577 (55.8% decrease) from $83,412 reported in the
same period ended 2016. During the current quarter, the Company incurred routine
travel and promotional costs. During first quarter 2016, the Company incurred
additional travel costs related to the process of exploring strategic options to
maximize shareholder value and to attend investment conferences.
Interest Expense
For the three months ended March
31, 2017, the Company reported $1,188,271 in interest expense which is an
increase of $254,579 (27.3% increase) from $933,692 reported in the same period
ended 2016. Interest expense increased due to a new loan agreement/balance. In
May 2016, the Companys wholly owned subsidiary (Idaho USG Holdings LLC) entered
into a loan agreement to finance the Companys development activities. The
original principal totaled $20.0 million and the principal at March 31, 2017 was
$19.3 million. The loan amount bears interest at a fixed rate of 5.8% per annum.
Net Income Tax Expense
For the three months ended
March 31, 2017, the Company reported net income tax expense of $153,000, which
was an increase of $45,000 (50.0% decrease) from the income tax expense of
$90,000 reported in the same period ended 2016. A significant factor in the tax
variance was attributed to the lower amount of non-controlling interest income.
Lower non-controlling interest income reduces the amount of income tax passed
through to those entities. The non-controlling interest variance and the other
significant variances that impact income tax expense are discussed in other
sections of this document.
-39-
Net Income Attributable to the Non-Controlling
Interests
The net income attributable to the non-controlling interest
entities is the line item that removes the portion of the total consolidated
operations that are owned by the Companys subsidiaries. For the three months
ended March 31, 2017, the Company reported $862,596 in net income attributable
to non-controlling interests, which was a decrease of $173,807 (16.8% decrease)
from $1,036,403 net income reported in the same period ended 2016. The primary
component of the variances were the operating results of USG Oregon LLC which
reported a subsidiary net profit for the three months ended March 31, 2017 of
$2,345,574, which was a decrease of $881,166 (27.3% decrease) from $3,226,740
subsidiary net profit reported in the same period ended 2016. The primary
conditions for the decreases in USG Oregon LLCs profits were discussed above.
The net income (loss) attributable to the non-controlling
interest entities is detailed as follows:
|
|
For the Three Months Ended
|
|
|
|
|
|
|
|
|
|
March 31,
|
|
|
|
|
|
|
|
Subsidiaries and Non-Controlling
|
|
2017
|
|
|
2016
|
|
|
Variances
|
|
Interest
Entities
|
|
$
|
|
|
$
|
|
|
$
|
|
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oregon USG Holdings LLC interest held by
Enbridge Inc.
|
|
927,170
|
|
|
1,284,086
|
|
|
(356,916
|
)
|
|
(27.8
|
)
|
Raft River Energy I LLC interest held by Goldman Sachs
|
|
(61,471
|
)
|
|
(243,819
|
)
|
|
182,348
|
|
|
74.8
|
|
Gerlach Geothermal LLC interest held by
Gerlach Green Energy, LLC
|
|
(3,103
|
)
|
|
(3,864
|
)
|
|
761
|
|
|
19.7
|
|
|
|
862,596
|
|
|
1,036,403
|
|
|
(173,807
|
)
|
|
(16.8
|
)
|
%
- represents the percentage
of change from 2016 to 2017
.
#
- Variance percentage
was extremely high or undefined.
Non-Controlling Interests
The following is a
summarized presentation of select financial line items from the statement of
operations by project and the impact of the related non-controlling interests
for the three months ended March 31, 2017:
|
|
|
|
|
|
|
|
|
|
|
Exploration
|
|
|
|
|
|
|
Neal Hot
|
|
|
|
|
|
|
|
|
Activities and
|
|
|
Consolid-
|
|
Statement of
|
|
Springs
|
|
|
San Emidio
|
|
|
Raft River
|
|
|
Corporate
|
|
|
ated
|
|
Operations Element
|
|
$
|
|
|
$
|
|
|
$
|
|
|
$
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross Profit (Loss)
|
|
2,723,928
|
|
|
912,043
|
|
|
55,086
|
|
|
167,192
|
|
|
3,858,249
|
|
Expenses/(Income)
|
|
406,004
|
|
|
486,972
|
|
|
(155
|
)
|
|
(4)
1,706,942
|
|
|
2,599,763
|
|
Net Income(Loss) before tax
expense
|
|
2,317,924
|
|
|
425,071
|
|
|
55,241
|
|
|
(1,539,750
|
)
|
|
1,258,486
|
|
Income taxes USG Portion
|
|
(522,000
|
)
|
|
(159,000
|
)
|
|
(44,000
|
)
|
|
590,000
|
|
|
(135,000
|
)
|
Non-controlling interests
|
|
(1)
(927,170
|
)
|
|
-
|
|
|
(2)
61,472
|
|
|
(3)
3,102
|
|
|
(862,596
|
)
|
Net income (loss) attributable to U.S.
Geothermal
|
|
868,754
|
|
|
266,071
|
|
|
72,713
|
|
|
(946,648
|
)
|
|
260,890
|
|
|
(1)
|
The non-controlling interest for Neal Hot Springs
represents a 40% interest for our joint venture partner,
Enbridge.
|
|
(2)
|
The non-controlling interest for Raft River represents 5%
of REC income and cash flows, and 99% of all remaining profits and losses
allocated to the Goldman Sachs Group.
|
-40-
|
(3)
|
The non-controlling interest for our exploration
activities represents an approximately 31% interest for our joint venture
partner at Gerlach, GGE Development.
|
|
(4)
|
Major costs included in Exploration Activities and
Corporate for the three months ended March 31, 2017
included:
|
|
|
Employee compensation
|
$ 911,734
|
|
|
|
Corporate administration
|
303,706
|
|
|
|
Professional fees
|
145,765
|
|
These costs are the responsibility of U.S. Geothermal Inc. (the
Parent Company) and cannot be allocated to projects. Once a project has been
classified as developmental, the costs associated with a project will be
capitalized.
Selected balance sheet items affected by non-controlling
interests as of March 31, 2017 are detailed as follows:
|
|
|
|
Non-
|
|
U.S.
|
|
|
|
|
|
Controlling
|
|
Geothermal
|
|
|
|
Consolidated
|
|
Interests
|
|
Inc.
|
|
Balance Sheet Items
|
|
$
|
|
$
|
|
$
|
|
|
|
|
|
|
|
|
|
Unrestricted cash and cash
equivalents
|
|
13,068,978
|
|
914,468
|
|
12,154,510
|
|
Restricted cash and security bonds:
|
|
|
|
|
|
|
|
Current
|
|
9,815,136
|
|
480,411
|
|
9,334,725
|
|
Long-term
|
|
18,605,059
|
|
5,260,125
|
|
13,344,934
|
|
Notes payable:
|
|
|
|
|
|
|
|
Current
|
|
3,892,026
|
|
1,301,000
|
|
2,591,026
|
|
Long-term
|
|
102,279,570
|
|
22,117,008
|
|
80,162,562
|
|
The loans held by the Company at March 31, 2017 are detailed as
follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
U.S.
Geothermal Inc.
|
|
|
|
Consolidated
|
|
|
|
|
|
|
|
|
Contracted
|
|
|
Loan
|
|
|
|
|
|
|
Total Loan
|
|
|
Remaining
|
|
|
Loan
|
|
|
Interest
|
|
|
Balance
|
|
|
Loan
|
|
|
|
Balances
|
|
|
Months to
|
|
|
Maturity
|
|
|
Rate
|
|
|
Portions
|
|
|
Balances
|
|
Descriptions
|
|
$
|
|
|
Term
|
|
|
End
Date
|
|
|
%
|
|
|
%
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Department of Energy
USG Oregon LLC
|
|
58,545,023
|
|
|
215
|
|
|
2/12/35
|
|
|
2.598
|
|
|
60.0
|
|
|
35,127,013
|
|
Prudential Group
USG Nevada LLC
|
|
29,038,580
|
|
|
249
|
|
|
12/31/37
|
|
|
6.750
|
|
|
100.0
|
|
|
29,038,580
|
|
Prudential Group
Idaho USG Holdings LLC
|
|
19,296,475
|
|
|
72
|
|
|
3/31/23
|
|
|
5.800
|
|
|
100.0
|
|
|
19,296,475
|
|
Chrysler Auto Loan
U.S. Geothermal Services
|
|
5,067
|
|
|
16
|
|
|
7/27/18
|
|
|
6.740
|
|
|
100.0
|
|
|
5,067
|
|
Totals
|
|
106,996,145
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
83,467,135
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
Average
Term (Months)
|
|
|
|
|
198
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
Average
Interest Rate
|
|
|
|
|
|
|
|
|
|
|
4.304
|
|
|
|
|
|
|
|
Off Balance Sheet Arrangements
As of March 31, 2017, the Company does not have any off balance
sheet arrangements.
-41-
Liquidity and Capital Resources
During the quarter ended March 31, 2017, the Companys
operating projects continued to generate significant available cash (after debt
service and reserves) to fund our development activities and corporate costs. In
addition, exercise of options and warrants generated $190,634 during the
quarter. We believe our cash and liquid investments at March 31, 2017 are
adequate to fund our general operating activities through December 31, 2018.
The Companys projects under development and under exploration
may require additional funding. In addition to government loans and grants
discussed below, we anticipate that additional funding may be raised through
financial and strategic partnerships, market loans, issuance of debt or equity,
and/or through the sale of ownership interest in tax credits and benefits. The
Company continues discussions with potential investors to evaluate alternatives
for funding at the corporate and project levels.
Idaho Power Company and Sierra Pacific Power (NV Energy),
continue to pay for their power in a timely manner. This power is sold under
long-term contracts at fixed prices. The status of the credit and equity markets
could delay our project development activities while we seek to obtain economic
credit terms or a favorable equity market price to further the drilling and
construction activities.
On May 19, 2016, the Company closed on a $20 million debt
facility from Prudential Capital Group. Under terms of the financing agreement,
the Company has the option, without obligation, to issue additional debt, up to
$50 million in aggregate within the next two years. The initial $20 million loan
has a fixed interest rate of 5.8% per annum. The loan principal amortizes over
twenty years, with a seven-year term. Principal and interest payments are made
semi-annually. The loan is collateralized with the Companys ownership interest
in the Neal Hot Springs and Raft River projects and by virtue of a pledge by the
Companys wholly owned subsidiary, U.S. Geothermal Inc., an Idaho corporation,
and sole member of Idaho USG Holdings, of the equity interests in Idaho USG
Holdings. The 22 MW Neal Hot Springs project is owned 60% by the Company and 40%
by Enbridge. The 13 MW Raft River project is owned 95% by the Company and 5% by
Goldman Sachs.
On January 25, 2016, management determined it would be prudent
to enter into a new Lincoln Park Capital (LPC) facility. The Companys first
Purchase Agreement with LPC, was entered into on May 21, 2012 and expired in
2015. Under the new Purchase Agreement, at the companys sole discretion, the
Company has the right to sell and LPC has the obligation to purchase up to $10
million of equity capital over a 30-month period subject to the conditions in
the Purchase Agreement. The agreement provided for an initial sale of $650,000
of shares of common stock upon closing. Net proceeds from LPCs investments were
used to cover a portion of the cost of the recent acquisition of the Goldman
Sachs ownership interest of the Raft River project, development of our
geothermal projects and for general corporate purposes. During the quarter ended
March 31, 2016 an additional $571,650 was raised under the At the Market (ATM)
subsequent to the initial sale. No additional funds were raised since that time.
Potential Acquisitions
The Company intends to continue its growth through the
acquisition of ownership or leasehold interests in properties and/or property
rights that it believes will add to the value of the Companys geothermal
resources, and through possible mergers with or acquisitions of operating power
plants and geothermal or other renewable energy properties.
Critical Accounting Policies
Our consolidated financial statements are prepared in
accordance with U.S. GAAP. In connection with the preparation of our
consolidated financial statements, we are required to make assumptions and
estimates about future events and apply judgments that affect the reported
amounts of assets, liabilities, revenue, expenses and the related disclosures. We base our
assumptions, estimates and judgments on historical experience, current trends
and other factors that we believe to be relevant at the time our consolidated
financial statements are prepared. On a regular basis, we review the accounting
policies, assumptions, estimates and judgments to ensure that our consolidated
financial statements are presented fairly and in accordance with U.S. GAAP.
However, because future events and their effects cannot be determined with
certainty, actual results could differ from our assumptions and estimates, and
such differences could be material.
-42-
There have been no significant changes to our critical
accounting estimates as discussed in our Annual Report.
Item 3 Quantitative and Qualitative Disclosures about
Market Risk
Interest Risk on Investments
At March 31, 2017, the
Company held investments of $32,639,791 in money market accounts. The money
market funds are invested in governmental obligations with minimal fluctuations
in interest rates and fixed terms; therefore, the interest rate risk on
investments is not significant.
Foreign Currency Risk
The Company is not subject to
foreign currency risks as we do not maintain a significant amount of cash
deposits in a foreign currency. At fiscal year end, the company held deposits
that amounted to less than $1,000 in U.S. dollar equivalents.
Commodity Price Risk
The Company is exposed to risks
surrounding the volatility of energy prices. These risks are impacted by various
circumstances surrounding the energy production from natural gas, nuclear,
hydro, solar, coal and oil. The Company has been able to mitigate, to a certain
extent, this risk by signing a power purchase contracts for a 20 to 25 year
period. This type of arrangement will be the model for power purchase contracts
planned for future power plants.
Item 4 - Controls and Procedures
An evaluation was performed under the supervision and with the
participation of our management, including the Chief Executive Officer (CEO)
and Chief Financial Officer (CFO), of the effectiveness of our disclosure
controls and procedures (as defined in Rule 13a-15(e) or 15d-15(e) under the
Securities Exchange Act of 1934, as amended) as of the end of the period covered
by this quarterly report. Based on that evaluation, our management, including
the CEO and CFO, concluded that our disclosure controls and procedures were
effective at the end of this period covered by this quarterly report to ensure
that information we are required to disclose in the reports that we file or
submit under the Securities Exchange Act of 1934, is recorded, processed,
summarized and reported within the time periods specified in the Securities and
Exchange Commissions rules and forms relating to us, including our consolidated
subsidiaries, and was accumulated and communicated to our management, including
our CEO and CFO, as appropriate, to allow timely decisions regarding required
disclosure.
There has been no change to our internal control over financial
reporting during the three months ended March 31, 2017 that has materially
affected, or is likely to materially affect, our internal control over financial
reporting.
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