News and Press Releases
Interim results for the six months to 30 June 2007
September 5, 2007
HIGHLIGHTS
-
Bank Financing agreed
- Net income slightly up
- Two new wells to be drilled at Tapia
- Steaming program about to start
Chairman, Jeremy Delmar-Morgan states that the financing, which has previously
held back Sefton's development, is now in place. This is the most significant
event for Sefton during the last few months and will mean that two new wells and
the steaming of two other wells will start in the next couple of weeks.
Chairman's Statement
The first half of 2007 has been one of consolidation as far as the trading
position is concerned. Oil production from the existing wells was relatively
steady at around 130 bopd. Oil and gas sales were down some 15% at $1.276m
($1.508m) but with general and administrative charges down 18% and oil and
production costs reduced by 23%, net income was slightly up on last year at
$179,134 ($175,647). Last year's figures included TEG Oil & Gas Canada,
which was sold during the period and provided a small trading income of $6,897.
The most significant event, however, for Sefton during the last few months has
been the signing of an agreement with the Bank of the West for a $10m line of
credit. We have started to drawn down an initial $1.5m, which will be invested
in the development program at Tapia. The Tapia oil field is the major source of
production and revenue for our wholly owned subsidiary, TEG USA. With the new
financing we are able to advance our drilling and steaming programmes at this
field. A rig will be on site in the next couple of weeks and two wells will be
drilled on the Hartje lease, which is the site of some of our best wells.
In addition we are preparing to start cyclic steaming at two wells located on
the Yule Lease. This Pilot Steam Test will provide invaluable data for planning
our full scale steam programme. Oil produced from the steaming, and any new
wells drilled, will move a significant amount of oil reserves into the Proved
Producing reserves category and increase the value of our operations
accordingly.
Once cash flow from the Tapia project increases, we will be able to pursue other
opportunities at Eureka Canyon. These include the drilling of one infill well
within the current producing area and conducting the second phase of the
geochemical mapping of Eureka's exploratory area.
At TEG MidContinent, we continue to believe that the opportunities are
extensive, but still take a cautious approach, selectively focusing on prime
acreage in our lease acquisition programme and undertaking geologic and
engineering studies. There has been increased industry activity adjacent to our
leased areas, the results of which support our belief in the areas potential.
Our acreage covers both oil and gas possibilities and is close to both existing
pipelines and drilling programs carried out by other operators in the area. We
believe that the best way forward will be with joint venture partners, but this
must be the right partnership for Sefton, allowing us to recoup some of our
investment and providing capital for drilling. We are currently in discussions
with a number of potential joint venture partners for developing both our
Leavenworth and Anderson/Franklin County assets. We will not make a decision
until we find the right partner, as this will be crucial to the Company reaping
the reward for its far sighted acquisition programme, which has been carried out
during the last few years.
We are now in an excellent position to start moving forward. The financing,
which has previously held back Sefton's development, is now in place. The terms
are very satisfactory and the draw down opportunities will increase as drilling
and steaming increase our production and reserves. Providing the first phase of
our drill and steaming program is successful we can look forward to developing
the Snow, Yule, Hartje, and Lackie leases at Tapia during 2008.
Jeremy Delmar-Morgan
Chairman
5 September 2007
For more information, please contact:
Jim Ellerton, Chairman and CEO Tel: +1 303 759 2700
Jeremy Delmar-Morgan, Chairman Tel: +44 77 8900 4874
David Millham, Investor Relations Tel: +44 20 7796 9999
Nicola Marrin/Jonathan Wright, Seymour Pierce Tel: +44 20 7107 8000
Consolidated Balance Sheets
June 30, June 30, December
31
2007 2006 2006
(unaudited) (unaudited) (audited)
---------- ---------- ----------
ASSETS
CURRENT ASSETS:
Cash $ 135,410 $ 148,350 $ 68,923
Accounts
receivable 192,735 578,223 372,174
Other
receivables -
related party 108,185 42,058 90,577
Prepaid
expenses and
other assets 1,975 31,223 19,849
---------- ---------- ----------
Total current
assets 438,305 799,854 551,523
OIL and GAS PROPERTIES
FULL COST
METHOD, net 7,861,600 7,386,719 7,517,673
EQUIPMENT AND
VEHICLES, net 43,410 58,883 47,957
---------- ---------- ----------
TOTAL ASSETS $ 8,343,315 $ 8,245,456 $8,117,153
========== ========== ==========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES:
Accounts
payable $ 406,391 $ 536,326 $ 484,443
Accrued
expenses 47,991 8,847 35,581
Accrued
expenses -
related
parties 77,884 78,895 25,000
Note payable,
current
portion 163,825 - 128,810
---------- ---------- ----------
Total current
liabilities 696,091 624,068 673,834
NOTES PAYABLE:
Note 681,485 910,100 705,056
payable
Note payable -
related party - 270,160 -
---------- ---------- ----------
681,485 1,180,260 705,056
---------- ---------- ----------
Less - -78,463 -
discount ---------- ---------- ----------
681,485 1,101,797 705,056
---------- ---------- ----------
ASSET RETIREMENT
OBLIGATION 134,440 162,167 134,440
---------- ---------- ----------
Total
liabilities 1,512,016 1,888,032 1,513,330
---------- ---------- ----------
STOCKHOLDERS EQUITY:
Common stock, no par value, 200,000,000
shares authorized,
115,109,527 shares
issued and
outstanding 12,790,863 12,026,845 12,742,521
Stock subscription
receivable -30,047 -30,047 (30,047)
Treasury stock -58,602 -58,602 (58,602)
Accumulated
(deficit) -5,870,915 -5,580,120 (6,050,049)
Accumulated
other comprehensive
income/loss 0 -652 -
---------- ---------- ----------
Total
stockholders'
equity 6,831,299 6,357,424 6,603,823
---------- ---------- ----------
TOTAL
LIABILITIES
AND
STOCKHOLDERS
EQUITY $ 8,343,315 $ 8,245,456 $8,117,153
========== ========== ==========
Consolidated Statement of Operations
For the Six Months Ended For the Year
Ended
June 30, June 30, 2006 December 31,
2007 2006
(unaudited) (unaudited) (audited)
------------ ------------ -------------
REVENUES:
Oil and gas sales $ 1,276,127 $ 1,508,114 $ 2,696,180
COSTS AND EXPENSES:
Oil and gas
production 274,967 356,104 833,716
Depletion and
depreciation 149,000 82,323 314,145
General and
administrative 644,434 785,689 1,478,696
Share based
compensation - - 447,957
------------ ------------ -------------
1,068,401 1,224,116 3,074,514
------------ ------------ -------------
INCOME (LOSS)
FROM
OPERATIONS 207,726 283,998 -378,334
------------ ------------ -------------
OTHER INCOME (EXPENSE):
Interest
income 66 6,231 6,738
Interest
expense (28,658) (114,582) (186,247)
Income from
TEG Canada - 6,894
Gain on sale
of TEG Canada - 14,865
Foreign
currency
transaction
exp - (56,693)
------------ ------------ -------------
(28,592) (108,351) (214,443)
------------ ------------ -------------
NET INCOME
(LOSS) $ 179,134 $ 175,647 $ (592,777)
============ ============ =============
Basic and
diluted gain
(loss) per
common share 0.0016 0.0016 (0.0058)
Basic and Diluted Weighted
average
shares
outstanding 115,109,527 1,629,158,744 115,109,527
============ ============ =============
Consolidated Statement of Cashflows
For the Six Months Ended For the Year
Ended
June 30, June 30, December 31,
2007 2006 2006
(unaudited) (unaudited) (audited)
------------ ------------ -------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income
(loss) $ 179,134 $ 175,647 $ (592,777)
Adjustments to reconcile net income
(loss) to net cash from
(used in) operating activities:
Depletion and depreciation 149,000 82,323 314,145
Amortization of discount on 78,463 119,000
convertible notes payable
Compensation expense related to stock - 447,957
options
Gain on disposal of subsidiary - (14,866)
Changes in operating assets and
liabilities:
Accounts receivable 161,831 (309,324) 96,324
Prepaid expenses 17,874 13,507 27,438
Other assets - related party - (19,541) (68,060)
Accounts payable (78,052) 202,466 (241,344)
Accrued expenses - related party 52,884 19,269 (54,058)
Accrued expenses 12,410 7,368 11,893
------------ ------------ -------------
Net cash provided by (used in) 495,081 250,178 45,652
operating activities ------------ ------------ -------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of
oil and gas
properties (488,380) (382,766) (738,790)
Purchase of
property and
equipment - (26,249) (27,492)
Acquisition of
minority
interest -
Canada - (36,484) -
Proceeds from
disposal of
subsidiary - - 284,728
Net cash
transferred
with
subsidiary - - (18,060)
------------ ------------ -------------
Net cash (used) by investing (488,380) (445,499) (499,614)
activities ------------ ------------ -------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from
notes payable 11,442 242,005 376,315
Payments on
notes payable - (41,059) -75,176
Proceeds from
sale of common
stock 48,342 42,305 38,944
------------ ------------ -------------
Net cash provided by financing 59,784 243,251 340,083
activities ------------ ------------ -------------
EFFECT OF
EXCHANGE RATE
CHANGES ON
CASH - (25,689) 56,693
------------ ------------ -------------
NET INCREASE
(DECREASE) IN
CASH AND CASH
EQUIVALENTS 66,485 22,241 (57,186)
CASH AND CASH
EQUIVALENTS ,
BEGINNING OF
YEAR 68,923 126,109 126,109
------------ ------------ -------------
CASH AND CASH
EQUIVALENTS,
END OF PERIOD 135,408 148,350 $ 68,923
============ ============ =============
Notes to Consolidated Financial Statements
-
The financial results for the half-year to 30 June 2007 and
the comparatives to 30 June 2006 are both unaudited. The financial information
for the year to 31 December 2006 has been extracted from the full audited financial
statements. The financial statements presented in the 30 June 2007 interim
statement incorporate by reference the full audit report that is available
in the Company's annual report from 31 December 31 2006.
-
The June 30, 2007 statements do not include the
Canadian Balance sheet items in consolidation or the Canadian operations
as a result of the sale of TEG Oil &
Gas Canada Inc. (Note 5). All other financial information included in this
document has been prepared on a consistent basis and using the same accounting
policies as the audited financial statements for the year to 31 December
2006 and has been approved by the Board of Directors of the Company.
-
The reporting currency of the Company is the U.S. dollar.
The functional currency of the Company's Canadian subsidiary was the Canadian
dollar. Translation into U.S. dollars is performed for assets and liabilities
at the exchange rate as of the balance sheet date. Income and expense accounts
are translated at average exchange rates for the reporting period. Adjustments
resulting from the translation are reflected as a separate component of other
comprehensive income. Transaction gains and losses that arise from exchange
rate fluctuations on transactions denominated in a currency other than the
functional currency are included in the results of operations as incurred.
-
On February 15, 2006 the Sefton Board of Directors
authorized the acquisition of shares in TEG Oil & Gas Canada, Inc. owned by minority interests. This was
completed with an offer to all TEG Oil & Gas Canada shareholders by way of an
exchange of Sefton shares for their shares owned in TEG Oil & Gas Canada, Inc.
or effective repayment of original investment. As of March 31, 2006, TEG Oil &
Gas Canada became a 100% wholly owned subsidiary of Sefton Resources, Inc.
-
On June 30, 2006 TEG Oil & Gas Canada Inc. was
sold by Sefton Resources, Inc. for $450,000.00 (Canadian) and 100% of the
shares of TEG MidContinent, Inc. The effective date of sale was May 1,
2006
-
As discussed in Note 5, TEG Oil & Gas Canada
was sold effective May 1, 2006 and oil and gas operations costs have been
included in the 2006 statements. Canadian oil and gas production costs
consist of actual figures through April 30, 2006
-
In accordance with Emerging Issues Task Force Issue
No.98 ("EITF 98-5"),
"Accounting for Convertible Securities with Beneficial Conversion Features or
Contingently Adjustable Conversion Ratios" and EITF Issue No. 00-27, Application
of Issue No 98-5 to Certain Convertible Instruments, the Company recognized
the advantageous value of conversion rights attached to convertible debt
as a discount to the related debt and an addition to capital in excess
of par value. As the market price exceeded the conversion price a beneficial
conversion feature of $157,000 was recorded at issuance. Amortization of
the discount of $78,463 is included in interest expense for the period
ended June 30, 2006.
-
Copies of the Interim Statement will be sent to shareholders
in October 2007. Copies of the Interim Statement will be available from the
Company Secretary, Masons Secretarial Services Limited, 30 Aylesbury Street,
London EC1R 0ER.