Item 2. Management’s Discussion and Analysis
of Financial Condition and Results of Operations.
The following is management’s discussion
and analysis of certain significant factors that have affected aspects of our financial position and the results of operations
during the periods included in the accompanying Condensed Financial Statements. You should read this in conjunction with the discussion
under “Management's Discussion and Analysis of Financial Condition and Results of Operations” and the audited Financial
Statements for the year ended June 30, 2018, included in our Annual Report on Form 10-K and the Consolidated Financial
Statements included elsewhere herein.
Throughout this report, a barrel of oil
or “Bbl” means a stock tank barrel (“STB”) and a thousand cubic feet of gas or “Mcf” means
a thousand standard cubic feet of gas (“Mscf”).
Overview
We are an independent energy company primarily
engaged in the acquisition, exploration, exploitation and development of oil and natural gas properties. Our principal business
is the exploration and development of oil and natural gas properties in the United States.
In June 2018 we signed a purchase and sale
agreement for the sale of the majority of our working interest in the Foreman Butte project in Montana and North Dakota for $40
million. This sale was expected to close on October 15, 2018 however the buyer failed to close. A non-refundable $1 million deposit
placed into escrow by the buyer was released to us and as such we have included it in “other income”. Following the
failure of the buyer to close, we are no longer holding the assets for sale in our balance sheet although efforts to sell the assets
continued. We terminated the purchase and sale agreement with the buyer and engaged PLS Energy Advisors Group to remarket the asset.
To the date of this report, we have not received any viable offers for the purchase of the assets and as such we continued our
discussions with a non-bank lender to consider refinancing our current Mutual of Omaha Bank credit facility. Due diligence was
completed during the current quarter and refinancing closed on April 9, 2019.
Foreman Butte Project
In March 2016 we closed on an acquisition
of certain producing and nonproducing oil and gas assets in North Dakota and Montana (the “Foreman Butte Project”)
for a purchase price of $16 million (the “Foreman Butte Acquisition”). The acquired assets were comprised of producing
oil and gas wells, shut in wells and associated facilities. The wells are located in the Madison and Ratcliffe formations. The
majority of these wells are now operated by us; however, a number of non-operated wells were also included in this package.
We continue to concentrate our efforts
on the operations of this field. Due to financial constraints we have not made substantial progress on the development of the PUD
drilling program in the Home Run Field. Our development efforts were constrained by our lack of access to capital to fund any development
activities. Subsequent to closing the refinancing on April 9, 2019 we began implementing our drilling program. We have four current
drilling permits for Home Run Field, the most promising non-producing area within the Foreman Butte Project.
Fiscal quarter overview
Our net oil production was 47,650 barrels
of oil for the quarter ended March 31, 2019, compared to 34,450 barrels of oil for the quarter ended March 31, 2018. Production
was higher during the quarter ended March 31, 2019 due to the impact of a number of workovers completed during the current quarter.
Our net gas production was 6,361 Mcf for
the quarter ended March 31, 2019 compared to 2,067 Mcf for the quarter ended March 31, 2018. The increase in the oil price has
meant that some of the more liquid rich gas has been produced rather than flared. This value is immaterial to us.
Lease operating expenses (“LOE”)
increased to $2.9 million for the quarter ended March 31, 2019, from $1.5 million for the quarter ended March 31, 2018 due to general
operating expense increases in the field due to increased production.
For the three months ended March 31, 2019
and March 31, 2018 we reported a net loss of $3.8 million from operations and a net loss of $2.0 million from operations, respectively.
See “Results of Operations”
below.
Notable Activities and Status of Material
Properties during the Quarter Ended December 31, 2018 and Current Activities
Producing Properties
Foreman Butte Project, McKenzie County,
North Dakota
Mississippian Madison Formation, Williston
Basin
Samson 87% Operated Average Working
Interest
During the quarter, we continued our water
flood pilot project for the Home Run Field. The waterflood pilot project utilizes an existing wellbore, the Mays 1-20H, which is
located on the flank of the field and is non-economic to produce for oil. The water flood is being used to add pressure to the
reservoir which is expected to enhance the recovery of oil. The well performance in the offsetting wells will be monitored to establish
the viability of the flood. The water being used is produced formation water so that there is no chemical compatibility issue.
In essence the water is being returned to the reservoir from which it originated. This water is trucked to the injector from the
existing producing wells. The water flood allowed us to resume production at certain wells that have been shut-in for the past
3 years. These shut-in wells were previously uneconomic to produce due to high water disposal costs. We cannot make assurances
regarding the success of the water flood operation.
The Home Run Field (also known as the Foreman
Butte Field) is the largest areal oil field in the Foreman Butte Project. It was developed on a 640-acre spacing pattern and our
engineering and geologic analyses have determined that only 3.2% of the original oil in place has been recovered to date. Given
that oil fields can recover up to 20% of their oil in place, there would appear to be significant undeveloped oil to be recovered
from this field.
Undeveloped Properties: Exploration
Activities
Hawk Springs Project, Goshen County,
Wyoming
Permo-Penn Project, Northern D-J Basin
Samson 37.5% working interest
All wells within this project have been
plugged and abandoned with the final work expected to be completed during the quarter.
Cane Creek Project, Grand & San
Juan Counties, Utah
Pennsylvanian Paradox Formation, Paradox
Basin
Samson 100% Working Interest
Our option to lease 8,080 net acres with
Utah SITLA (Utah School and Institutional Trust Lands Administration) at a cost of $75 per acre expired on November 30, 2017, unexercised.
$0.3 million in undeveloped capitalized costs was written off in the three months ended December 31, 2017.
Developed Properties: Drilling
Activities
Rainbow Project, Williams County, North Dakota
Mississippian Bakken Formation, Williston Basin
Samson 23% and 52% working interest
Kraken Operating, LLC, the operator of
the Gladys 1-20H well, has been producing this well at an average rate of 146 BOPD and 172 MCFPD during the quarter.
Results of Operations
For the three months ended March 31, 2019
we reported a net loss of $3.8 million compared to a net loss of $2.0 million for the same period in 2018.
For the nine months ended March 31, 2019
we reported a net loss of $4.9 million compared to a net loss of $5.2 million for the same period in 2018.
The following tables set forth selected
operating data for the three months ended:
|
|
Three months ended
|
|
|
|
31-Mar-19
|
|
|
31-Mar-18
|
|
Production Volume
|
|
|
|
|
|
|
|
|
Oil (Bbls)
|
|
|
48,449
|
|
|
|
34,450
|
|
Natural gas (Mcf)
|
|
|
8,055
|
|
|
|
2,067
|
|
BOE (Barrels of oil equivalent - based on one barrel of oil to six Mcf of natural gas)
|
|
|
49,792
|
|
|
|
34,795
|
|
|
|
|
|
|
|
|
|
|
Sales Price
|
|
|
|
|
|
|
|
|
Realized Oil ($/Bbls)
|
|
$
|
49.35
|
|
|
$
|
53.90
|
|
Impact of settled derivative instruments
|
|
$
|
(5.34
|
)
|
|
$
|
(15.89
|
)
|
Derivative adjusted price
|
|
$
|
44.02
|
|
|
$
|
38.01
|
|
|
|
|
|
|
|
|
|
|
Expense per BOE:
|
|
|
|
|
|
|
|
|
Lease operating expenses
|
|
$
|
57.42
|
|
|
$
|
43.28
|
|
Production and property taxes
|
|
$
|
5.12
|
|
|
$
|
5.51
|
|
Depletion, depreciation and amortization
|
|
$
|
9.01
|
|
|
$
|
9.24
|
|
General and administrative expense
|
|
$
|
17.01
|
|
|
$
|
26.86
|
|
|
|
Nine months ended
|
|
|
|
31-Mar-19
|
|
|
31-Mar-18
|
|
Production Volume
|
|
|
|
|
|
|
|
|
Oil (Bbls)
|
|
|
172,924
|
|
|
|
134,366
|
|
Natural gas (Mcf)
|
|
|
44,076
|
|
|
|
13,217
|
|
BOE
|
|
|
180,270
|
|
|
|
136,569
|
|
|
|
|
|
|
|
|
|
|
Sales Price
|
|
|
|
|
|
|
|
|
Realized Oil ($/Bbls)
|
|
$
|
51.16
|
|
|
$
|
52.57
|
|
Impact of settled derivative instruments
|
|
$
|
(4.48
|
)
|
|
$
|
(7.54
|
)
|
|
|
$
|
46.67
|
|
|
$
|
45.03
|
|
Expense per BOE:
|
|
|
|
|
|
|
|
|
Lease operating expenses
|
|
$
|
46.26
|
|
|
$
|
32.27
|
|
Production and property taxes
|
|
$
|
5.61
|
|
|
$
|
4.73
|
|
Depletion, depreciation and amortization
|
|
$
|
8.38
|
|
|
$
|
8.93
|
|
General and administrative expense
|
|
$
|
14.56
|
|
|
$
|
22.94
|
|
The following table sets forth results
of operations for the following periods:
|
|
Three months ended
|
|
|
|
|
|
|
31-Mar-19
|
|
|
31-Mar-18
|
|
|
3Q19 to 3Q18 change
|
|
Oil sales
|
|
$
|
2,391,155
|
|
|
$
|
1,856,904
|
|
|
$
|
534,251
|
|
Gas sales
|
|
|
84,912
|
|
|
|
20,424
|
|
|
|
64,488
|
|
Other liquids
|
|
|
2,701
|
|
|
|
2,938
|
|
|
|
(237
|
)
|
Interest income
|
|
|
92
|
|
|
|
89
|
|
|
|
3
|
|
Gain on derivative instruments
|
|
|
-
|
|
|
|
-
|
|
|
|
-
|
|
Lease operating expense
|
|
|
(2,858,848
|
)
|
|
|
(1,505,990
|
)
|
|
|
1,352,858
|
|
Depletion, depreciation and amortization
|
|
|
(448,627
|
)
|
|
|
(321,561
|
)
|
|
|
127,066
|
|
Abandonment
|
|
|
(51,402
|
)
|
|
|
(59,536
|
)
|
|
|
(8,134
|
)
|
Exploration and evaluation expenditure
|
|
|
(11,000
|
)
|
|
|
(14,030
|
)
|
|
|
(3,030
|
)
|
Accretion of asset retirement obligations
|
|
|
(368,674
|
)
|
|
|
(79,307
|
)
|
|
|
289,367
|
|
Interest expense
|
|
|
(395,347
|
)
|
|
|
(337,472
|
)
|
|
|
57,875
|
|
Loss on derivative instruments
|
|
|
(1,298,610
|
)
|
|
|
(461,395
|
)
|
|
|
837,215
|
|
Amortization of borrowing costs
|
|
|
-
|
|
|
|
(132,535
|
)
|
|
|
(132,535
|
)
|
General and administrative
|
|
|
(846,919
|
)
|
|
|
(934,504
|
)
|
|
|
(87,585
|
)
|
Net income/(loss)
|
|
$
|
(3,800,567
|
)
|
|
$
|
(1,965,975
|
)
|
|
$
|
1,834,592
|
|
|
|
Nine months ended
|
|
|
|
|
|
|
31-Mar-19
|
|
|
31-Mar-18
|
|
|
3Q18 to 3Q17
|
|
Oil sales
|
|
$
|
8,846,003
|
|
|
$
|
7,063,419
|
|
|
$
|
1,782,584
|
|
Gas sales
|
|
|
227,653
|
|
|
|
105,714
|
|
|
|
121,939
|
|
Other liquids
|
|
|
11,534
|
|
|
|
6,118
|
|
|
|
5,416
|
|
Interest income
|
|
|
543
|
|
|
|
202
|
|
|
|
341
|
|
Gain on derivative instruments
|
|
|
-
|
|
|
|
-
|
|
|
|
-
|
|
Other
|
|
|
1,000,000
|
|
|
|
178,657
|
|
|
|
821,343
|
|
Lease operating expense
|
|
|
(8,339,180
|
)
|
|
|
(4,406,993
|
)
|
|
|
(3,932,187
|
)
|
Depletion, depreciation and amortization
|
|
|
(1,510,598
|
)
|
|
|
(1,219,726
|
)
|
|
|
(290,872
|
)
|
Abandonment Expense
|
|
|
(51,402
|
)
|
|
|
(126,212
|
)
|
|
|
74,810
|
|
Exploration and evaluation expenditure
|
|
|
(50,311
|
)
|
|
|
(296,543
|
)
|
|
|
246,232
|
|
Accretion of asset retirement obligations
|
|
|
(646,030
|
)
|
|
|
(239,193
|
)
|
|
|
(406,837
|
)
|
Interest expense
|
|
|
(1,151,485
|
)
|
|
|
(916,346
|
)
|
|
|
(235,139
|
)
|
Loss on derivative instruments
|
|
|
(863,266
|
)
|
|
|
(2,030,261
|
)
|
|
|
1,166,995
|
|
Amortization of borrowing costs
|
|
|
-
|
|
|
|
(190,434
|
)
|
|
|
190,434
|
|
General and administrative
|
|
|
(2,624,788
|
)
|
|
|
(3,133,074
|
)
|
|
|
508,286
|
|
Net loss
|
|
$
|
(5,151,327
|
)
|
|
$
|
(5,204,672
|
)
|
|
$
|
53,345
|
|
Comparison of three months and nine
months ended March 31, 2018 to three months and nine months ended March 31, 2019
Oil and gas revenues
Oil revenues increased from $1.8 million
for the three months ended March 31, 2018 to $2.4 million for the three months ended March 31, 2019, as a result of the increase
in oil production. Oil production increased from 34,450 bbls for the three months ended March 31, 2018 to 47,650 bbls for the three
months ended March 31, 2019.
The realized oil price decreased from $51.16
per Bbl for the three months ended March 31, 2018 to $49.35 per Bbl (excluding the impact of derivatives) for the three months
ended March 31, 2019 following a recent decline in the global oil price.
Gas revenues increased from $0.02 million
for the three months ended March 31, 2018 to $0.08 million for the three months ended March 31, 2019 as a result of increased production.
Oil revenues increased from $7.1 million
for the nine months ended March 31, 2018 to $8.8 million for the nine months ended March 31, 2019. The increase in revenue is a
result of the increase in production from 134,366 bbls for the nine months ended December 31, 2018 to 171,634 bbls for the nine
months ended March 31, 2019.
Gas revenues increased from $0.1 million
for the nine months ended March 31, 2018 to $0.2 million for the nine months ended March 31, 2019.
Sale of Assets
No sales of assets were recorded in the
three months ended March 31, 2019 or 2018.
For the nine months ended March 31, 2019
we recognized $1.0 million in profit on the partial proposed sale of the Foreman Butte project. At the signing of the purchase
and sale agreement in June 2018 a deposit of $1 million was placed into escrow by the purchaser. Following the failure of the buyer
to close on the transaction in September 2018, the escrow was released to the Company.
Exploration expense
Excluding deferred exploration costs written
off, exploration expenditures for the quarters ended March 31, 2019 and March 31, 2018 were less than $15,000 for either quarter.
For the nine month ended March 31, 2019, this expenses was $59,311 compared to $296,543 for the nine months ended March 31, 2018.
Lease operating expense
Lease operating expenses (“LOE”)
increased from $1.5 million for the quarter ended March 31, 2018, to $2.9 million for the quarter ended March 31, 2019 due to increased
production. The wells in the Foreman Butte project area and in the Home Run Field are also older wells than those we have previously
owned and require additional fresh water and hot oil cleanouts which may increase operating costs of the wells. We are continuing
to review our lease operating expenses and will shut wells in that are not economic to produce in the current oil pricing environment.
We also performed a number of workovers at a cost of $0.3 million (included in LOE) during the quarter to increase and maintain
production during the quarter. Workovers will likely need to completed from time to time. It is expected that these workovers will
be completed, if possible, using our rig.
Lease operating expense increased from
$4.4 million for the nine months ended March 31, 2018 to $8.1 million for the nine months ended March 31, 2019. This increase was
due to an increase in production and an increase in oil field costs. Also included in lease operating expense is $1.4 million in
workover costs. As the field is an older field, workovers are required from time to time. It is expected that workovers will be
completed using the rig we own.
Depletion, depreciation and amortization
expense
Depletion, depreciation and amortization
increased from $0.3 million for the quarter ended March 31, 2018 to $0.4 million for the quarter ended March 31, 2019. Following
the change in status from assets held for sale to remaining in continuing operations, depletion, depreciation and amortization
expense has been calculated since the assets were initially held for sale. Depletion, depreciation and amortization booked in the
current quarter covers the period from April 2018 to December 2018.
Depletion, depreciation and amortization
expense increased to $1.5 million for the nine months ended March 31, 2019 from $1.2 million for nine months ended March 31, 2018.
General and administrative expense
General and administrative expense decreased
from $0.9 million for the quarter ended March 31, 2018 to $0.8 million for the quarter ended March 31, 2019. We have been actively
trying to reduce our general and administrative costs in recent periods. Effective October 1, 2017, all staff and directors took
25% pay cuts in order to reduce salary costs. The cost of a number of consultants has also been reduced.
General and administrative expense decreased
from $3.1 million for the nine months ended March 31, 2018 to $2.6 million for the nine months ended March 31, 2019.
Cash Flows
The table below shows cash flows for the
following periods:
|
|
Nine months ended
|
|
|
|
31-Mar-19
|
|
|
31-Mar-18
|
|
Cash provided by/(used in) operating activities
|
|
$
|
(863,479
|
)
|
|
$
|
507,473
|
|
Cash (used in)/provided by investing activities
|
|
|
569,199
|
|
|
|
(644,931
|
)
|
Cash provided by/(used in) financing activities
|
|
|
-
|
|
|
|
414,843
|
|
Cash flow from operations decreased from
$0.5 million for the nne months ended March 31, 2018, to a net outflow of $0.3 million for the nine months ended March 31, 2018.
Cash receipts from customers increased from $8.5 million for the nine months ended March 31, 2018 to $8.8 million for the nine
months ended March 31, 2019 following an increase in production.
Payments to suppliers and employees increased
from $6.0 million for the nine months ended March 31, 2018 to $7.0 million for the nine months ended March 31, 2019. Payments for
derivative instruments decreased from $1.0 million for the nine months ended March 31, 2018 to $0.9 million for the nine months
ended March 31, 2019.
Cash used in investing activities increased
from an outflow of $0.6 million for the nine months ended March 31, 2018 to an inflow of $0.02 million for the nine months ended
March 31, 2019 following the receipt of previously escrowed funds relating to the sale of assets that failed to close.
The majority of options outstanding as
at March 31, 2019 are currently out of the money.
Liquidity, Capital Resources and Capital
Expenditures
Our primary use of capital has been acquiring,
developing and exploring oil and natural gas properties.
On February 9, 2018 we entered
into an agreement (the “Agreement”) with Mutual of Omaha Bank. Under the Agreement we were required to provide
Mutual of Omaha Bank, on or before March 31, 2018, with either (a) an executed purchase and sale agreement evidencing the
sale of Samson and its subsidiaries or its respective businesses and assets, or (b) a fully-executed letter of intent or
other form of commitment letter from a credible lender or other financing source reflecting a proposed refinance or payment
of Samson’s outstanding obligations. Following our breach of the Agreement and multiple breaches of the covenants in
the amended credit facility, on June 14, 2018 we entered into a forbearance agreement with Mutual of Omaha Bank pursuant to
which the Bank agreed to forbear on exercising its remedies under the credit facility contingent upon the success of our
effort to sell the Foreman Butte Project. This agreement, as amended, terminated in accordance with its terms on October 15,
2018. The $23.9 million outstanding under our credit facility was due for repayment October 31, 2018 but we did not repay it
by that deadline. As a result, Mutual of Omaha Bank had the right to issue a notice of default and seek repayment of the
facility or pursue alternative repayment methods, including the sale of the outstanding loan to a third party, at any
time.
It was our intention to repay the outstanding
credit facility with the proceeds from the contracted sale after closing on October 15, 2018, however this sale failed to close.
Mutual of Omaha Bank had the right to issue us with a notice of default in relation to the facility.
The current balance due under the facility
was $23.9 million and was due for repayment October 31, 2018. This loan was refinanced subsequent to quarter end.
On April 9, 2019 Samson Oil and Gas, USA,
Inc., a wholly owned subsidiary of Samson oil and Gas Limited, closed a $33.5 million refinancing with AEP I FINCO LLC. The
new facility has a 5 year term and an interest rate of LIBOR + 10.5%. The proceeds of the new debt facility were used to retire
the existing line of credit, repay outstanding creditors and to provide working capital to pursue an infill drilling program.
The repayment of this facility and compliance with covenants will depend on our ability to be successful in our drilling program
as discussed below.
Our main source of liquidity during the
three months ended March 31, 2019 was cash on hand and the release of escrow funds from the terminated sale of assets.
During the prior four fiscal years, our
three main sources of liquidity were (i) borrowings under our credit facility, (ii) equity issued to raise $21.4 million and (iii)
our tax refund of $5.6 million from the Internal Revenue Service, received in February 2013. During the years prior to the fiscal
year ended June 30, 2012, our primary sources of liquidity were the sale of acreage and other oil and gas assets.
Our cash position as of March 31, 2019
decreased slightly from June 30, 2018 largely due an increase in our accounts payable balance and the release of escrow funds from
the termination of the purchase agreement for our Foreman Butte assets.
Our main source of liquidity during the
three months ended March 31, 2019 was cash on hand.
If future production rates are less than
anticipated, and/or the oil price deteriorates for an extended period, the value of our position in affected areas will decline,
our results of operations, financial condition and liquidity will be adversely impacted and we could incur material write-downs
of oil and gas properties. Our ability to continue operations could also be adversely affected. See the risk factors in our Annual
Report on Form 10-K for the fiscal year ended June 30, 2018. See also Part II, Item 1A of this report below.
Off-Balance Sheet Arrangements
Since our inception, we have not engaged
in any off-balance sheet arrangements, including the use of structured finance, special purpose entities or variable interest entities.
Looking Ahead
We plan to focus on the following objectives
in the coming 12 months:
|
·
|
Undertaking 8 well drilling program;
|
|
·
|
Continued focus on cost savings and efficiency
across all aspects of the Company, including lease operating costs and general and administrative costs; and
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Strengthening the balance sheet through
diligent capital management.
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As a consequence of this refinancing the
Company has embarked on an infill development program. The drilling program is designed to drill horizontal laterals from the existing
well bores. The ability to drill out of an existing wellbore has made the economics of these development wells attractive, given
the ability to use surface facilities associated with the existing well. The next 12 months should see a total of 8 similar lateral
wells drilled within the Home Run Field, which is the largest (by area) of the oil fields in Samson’s portfolio. The Company
has in its portfolio a total of 26 PUD locations that management expects will provide an excellent growth platform. The debt funding
that has been achieved in this transaction is expected to provide sufficient working capital to initiate and maintain the planned
development drilling program.