Just gone up to 10.5 on the offer--- good luck Marcel.
2517

So you have 0.1m in value, Marcel, and you're not sure about how the MM's operate the bid:offer game? Mmh.....?

I now im risk taker.

OK, if that is the case, then I wish you well, sir. Good luck!

Thankyou

ser or goo who will have the good news first, good luck.

Who cares I'm heavily armed with both!!! Marcel, nice holding, all the best.

Anyone know when SER are going to annouce there results?

results for ser are in.good news.

morning all
excellent results

Sefton Resources Inc
22 September 2006


SEFTON RESOURCES, INC.
('Sefton' or 'The Company')

Interim results for the six months to
30 June 2006

HIGHLIGHTS

o Sefton records its first interim profit
o Sales up 306% at $1.5m
o Profit of $175,647 (loss $1,008,626)
o Plans in hand for at least five new wells

Chairman, Jim Ellerton reports that 'the company is financing operations from
cash flow while discussing a line of credit with several banking institutions. A
line of credit will allow the company to accelerate the development and expand
its assets, in California and Kansas'.

Chairman's Statement:
I am pleased to report the first profit statement of the Company:

Oil and Gas Sales for the six-month period ending 30 June 2006 were $1,508,114 a
306% increase over the comparable period last year ($371,414), but slightly down
from the second half of last year due to the repair work at Tapia and Eureka
that was reported in my 1 August 2006 statement.

Production costs increased 74% to $356,104 ($204,947), primarily as a result of
the aforementioned repair work. General and administrative costs decreased 4% to
$785,689 ($815,994). Overall costs and expenses decreased 3% to $1,332,467
($1,380,040), despite a $78,463 non-cash interest expense related to an equity
conversion option in a loan note. These resulted in a profit of $175,647 for the
six-month period, a 118% increase over the loss of $1,008,626 for the comparable
period last year.

On the balance sheet, the current assets exceed the current liabilities. Total
liabilities were reduced and shareholders' equity increased significantly for
the period ending 30 June 2006 relative to the comparative period in 2005.

The sale of TEG Oil & Gas Canada, Inc. closed June 30, 2006 with an effective
date of May 1, 2006 and the Company realized approximately $400,000 USD cash and
at the same time increased its holdings to 100% of the shares in TEG
MidContinent, Inc., which contain significant Eastern Kansas landholdings.

Following the sale of TEG Canada, which accounted for 30-40 BOPD and the
successful repair work at Tapia and Eureka, production has now settled down at
140 BOPD at Tapia and 15-20 BOPD at Eureka. Plans are in hand for at least five
new wells, but these are subject to rig availability, which remains very tight.

Subsequent to June 30, 2006, an initial ruling on the remaining litigation to
claim damages against the drilling company following the 2002 Blowout went
against the Company and we are awaiting an analysis of the Ruling and options
available to the Company from our lawyers. The Company's balance sheet includes
the contingent liability ($178,000) from the remaining litigation and as such,
there will be no impact to the Company's financials, if we choose to settle this
litigation.

Currently the Company is financing Operations from Cash flow, while discussing a
line of credit with several banking institutions. A line of credit will allow
the Company to accelerate the development and expand its assets in California
and Kansas.

Operations reports for the Company's two wholly owned subsidiaries follow.

Jim Ellerton
Chairman and Chief Executive Officer
September 22, 2006

Interim Operations Report on TEG Oil & Gas USA, Inc.

TAPIA OIL FIELD

TEG USA concentrated on facilities improvements during the first half of 2006.
The better than expected results from the 2005 drilling program put a strain on
the old tank and separation equipment at the Tapia Oil Field. Capital
expenditures could not be justified, however, without first proving the
viability of new wells in the field. The 2006 program for upgrading the
facilities includes repair and or replacement of three tanks at the Lackie
facility, four tanks at the Hartje facility, Installation of a vapor recovery
and gas flare system, upgrade of tank piping at the Yule tank facility and
realignment of the produced water separation and injection system. Through June
30, 2006 TEG USA had completed 80% of the Lackie facility Tank reconstruction,
100% of the Yule tank piping improvements, Reconstruction of the Hartje/Lackie
Produced Water Tank, and 100% of the Tapia Vapor Recovery/Gas Flare System. We
are on schedule for completing the proposed tasks by year-end. Once completed,
the tank work will add an additional 2,000 barrels of storage capacity at Tapia
and significantly greater daily throughput capacity.

Production at Tapia for the first six months of the year averaged 130 BOPD
despite key wells being down for mechanical reasons for over two months while
waiting for a well servicing rig. The increased activity in the California oil
market has made service rigs especially scarce. While the service rig was at the
field, TEG conducted an acid stimulation of one well that had historically low
fluid production rates. The acid stimulation resulted in an increase from 1 BOPD
to approximately 10 BOPD. Additionally TEG took the opportunity to replace pumps
in all of the key wells so not to risk pump failures in wells after the rig was
released and no longer available. Once all service rig work was completed, the
production for the field returned to expected production rates of approximately
150 BOPD.

TEG USA revenues averaged $251,352/mo. for the January through June 2006 time
period, dominantly from oil produced at Tapia. This facilitated the payout of
the 2005 five well drilling program as well as funding 2006 facilities projects.

TEG has received approval for five of the nine wells from the California
Division of Oil, Gas and Geothermal Resources. Approval of another four wells,
which will be drilled on Federal minerals parcels, are pending surface owner
sign-off (Los Angeles County) before final approval is granted by the U.S.
Bureau of Land Management. TEG is now in the process of securing a drilling rig
to begin the next round of drilling at Tapia. Rig availability, however,
continues to be very tight.

EUREKA CANYON OIL FIELD

TEG has been working with W.L. Gore and Associates, Inc. at Eureka Canyon in
preparation for a geochemical reconnaissance-mapping program. Gore Geochemical
surveys have shown great success worldwide in the identification of prospect
areas and in reducing drilling risk within existing mapped areas. The area under
minerals lease to TEG comprises just over 1,500 acres in rugged terrain. This
rugged terrain and steeply dipping geology makes acquisition of standard
subsurface seismic data a challenge. TEG currently produces oil from about 40
acres within this property. We anticipate that the survey will provide TEG with
new areas to concentrate exploitation efforts and also add support for two
possible infill-drilling locations identified by production mapping of the oil
producing area. This program is on track for 3rd Quarter 2006 implementation.

EVENTS SUBSEQUENT TO JUNE 30, 2006

Since the close of the 2nd Quarter TEG has signed a formal contract for services
with W.L.Gore and is at this time in the process of collecting the field
geochemical samples at Eureka Canyon. Once collected, the samples will be
analyzed and compared to samples from similar, known oil producing areas as well
as non-oil-producing areas for calibration. A prospect map will then be
generated for the area.

TEG USA took the opportunity to conduct pump changes and well clean outs during
late July and early August at Eureka Canyon while a service rig was available.
The work resulted in restoring production from less than 10 BOPD to
approximately 20 BOPD.

TEG has continued to upgrade the facilities at Tapia and has received delivery
of new tank panels for repair of the two 1,000 bbl Hartje stock tanks. We have
also received bids on tank insulation and heating equipment that will facilitate
better oil separation processing during the cold winter months. All Lackie tanks
are reconstructed and tank piping is now being completed.

Harry P, Barnum, P.G., R.E.A.
President / Managing Director
TEG Oil & Gas USA, Inc.

Interim Operations Report for TEG MidContinent, Inc.

At the start of 2006, the company had improved its asset base and had positioned
itself for future development and growth. During the first six months of the
year TEG has moved cautiously; selectively focusing on prime acreage in its
lease acquisition program and undertaking geological and engineering studies
prior to initiating its drilling program. This less aggressive approach allows
others in the industry to perfect drilling and completion technologies unique to
the Forest City Basin that TEG can utilized once drilling commences. Meanwhile
the company's leasehold is situated in geologically prime areas and as indicated
below, industry drilling activity and successes supports TEG's project
development decisions and its leasehold value has increased. These favorable
factors give TEG the option to undertake its drilling program individually or
through joint venture.
TEG MIDCONTINENT PROJECTS:

Leavenworth County

We have continued to acquire leases in Leavenworth County, an area which TEG
management believes is a very viable project. Leavenworth County has produced
almost 3 million barrels of oil and in excess of 18 BCF of gas. There remains
considerable, undrilled, geologically sound prospects in addition to the
unconvential Coalbed Methane potential

Believing this, TEG is undertaking the following two-phase approach to project
development:
Lease Acquisition
During the 'Due diligence' phase of the attempted acquisition it was discovered
that considerable un-leased/open acreage was situated adjacent to existing
wells. The Company initiated a lease acquisition program and today TEG has
increased its total acreage holdings to over 7500 acres acquired at competitive
lease bonus costs.

Joint Venture Development
Currently TEG is in contract negotiations with several pipeline Operators that
provide gas gathering system infrastructure or market access. One Operator has
immediate access to the Southern Star system and is situated such that access
could be achieved via a previous 'tap' that needs only equipment upgrades to
start deliveries. This pipeline could provide immediate market access
('hook-up') for several wells. The contract negotiations with these operators
should be concluded during the fourth quarter of 2006.

Anderson / Franklin County

The Anderson and Franklin County leasehold is considerable, has close proximity
to pipelines and is supported by extensive geology and coalbed methane
production within the Forest City Basin, in the immediate area of TEG's project.

At the end of June TEG had leased in excess of 28,000 acres. The Leases were
acquired at competitive prices. All leases are for a minimum of five (5) years,
with most having an option to extend for an additional five (5) years. The
acreage is situated such that TEG has coverage on both conventional oil and gas
possibilities and on the thicker, potentially more productive, Bevier and
Riverton coal deposits. The existence of abandoned or temporarily abandoned
well-bores on the leased acreage will provide TEG with the opportunity to test
various potentially productive zones

The Forest City Basin/Bourbon Arch CBM development play is moving toward TEG's
acreage and supports TEG's drilling optimism or ability to attract joint venture
partners. This statement is based upon project development by Petrol on the West
(19 wells recently completed, and 12 additional wells permitted, three that are
immediate offsets to TEG acreage). Petrol is selling gas into the Enbridge
system that crosses TEG acreage. Heartland has initiated four pilot projects in
an area east of TEG's acreage and has successfully completed 24 wells. Heartland
is selling gas into the Enbridge system.

The opportunities in Kansas are extensive. In order to better quantify the
opportunities, TEG has contracted Sure Engineering to consolidate and expand
available data into a TEG Kansas Operational Study, upon completion of that
report TEG will determine its best courses of action relative to both projects.

Bruce Mackay
President
TEG MidContinent, Inc.


Sefton Resources Inc.
Consolidated Statements of Operations and Comprehensive Income (Loss)

For the six months For the year ended December
ended June 30 31 2005

2006 2005 (audited)
(unaudited) (unaudited)
Revenues:
Oil and gas sales $1,508,114 $371,414 $2,165,410

Cost and Expenses:
Oil and gas production 356,104 204,947 469,196
Depletion and
Deprecation 82,323 98,013 199,714
General and
administrative 785,689 815,994 1,885,406
Loss on fair value
of guarantee - 266,735 266,735
----------- ---------- -------------
1,224,116 1,385,689 2,821,051
----------- ---------- -------------
Income (Loss) from
Operations 283,998 (1,014,275) (655,641)
=========== ========== =============

Other Income(expense):
Interest income 6,231 13,911 15,421
Interest expense
(Note 10) (114,582) (8,262) (84,193)
Foreign currency
transaction exp - - (8,051)
----------- ---------- -------------
(108,351) 5,649 (76,823)
----------- ---------- -------------
Net Income (Loss) $175,647 ($1,008,626) ($732,464)
----------- ---------- -------------

Basic and diluted
gain (loss) per
common share: 0.0001 (0.001) (0.0005)

Basic and Diluted
Weighted average
shares outstanding 1,580,396,376 1,493,369,500 1,493,369,500
=========== ========== =============


Sefton Resources, Inc.
Consolidated Balance Sheets
---------- ---------- -------------
Assets June 30 June 30 December 31
2006 2005 2005
(unaudited) (unaudited) (audited)
---------- ---------- -------------
Current Assets:
---------- ---------- -------------
Cash 148,350 $516,231 $126,109
Accounts receivable 578,223 140,906 347,710
Other receivables - related party 42,058 88,286 22,517
Prepaid expenses and other assets 31,223 19,062 47,287
---------- ---------- -------------
Total current assets 799,854 764,485 543,623

Lease Acquisition-Intangible
Canada Sale (Note 9) 1,234,484

Oil and gas properties full
cost method, net 7,386,719 7,336,000 7,524,772
Equipment and vehicles, net 58,883 58,903 50,126
---------- ---------- -------------

Total assets 9,479,940 $8,159,388 $8,118,521
========== ========== =============

Liabilities and Stockholders
Equity
Current Liabilities:
---------- ---------- -------------
Accounts payable 536,326 $1,710,036 $774,276
Accrued expenses 8,847 29,556 23,685
Accrued expenses - related parties 78,895 - 79,058
Note payable, current portion - - 18,000
---------- ---------- -------------
Total current liabilities 624,068 1,739,592 895,019

Notes payable:
---------- ---------- -------------
Note payable 910,100 533,749 653,227
Note payable - related party 270,160 - 270,160
---------- ---------- -------------
1,180,260 533,749 923,387
Less discount (78,463) - (119,000)
---------- ---------- -------------
Total notes payable 1,101,797 533,749 804,387

Asset Retirement Obligation 162,167 292,612 163,111
---------- ---------- -------------
Total Liabilities 1,888,032 2,032,204 1,862,517
---------- ---------- -------------

Minority interest - 407,865 722,072
---------- ---------- -------------

Stockholders Equity:
---------- ---------- -------------
Common stock, no par value, 3,000,000,000 shares
authorised, 1,629,158,744 (June 30, 2006),
1,493,365,500 (June 30, 2005)
and 1,493,369,500 (December
31, 2005) shares issued and
outstanding 12,026,845 10,974,689 11,079,853
Stock subscription receivable (30,047) (30,047) (30,047)
Treasury stock (58,602) (58,602) (58,602)
Accumulated (deficit) (4,345,636) (5,797,961) (5,521,799)
Accumulated other
comprehensive income/loss (652) 97,491 64,527
---------- ---------- -------------
Total stockholder's equity 7,591,908 5,185,570 5,533,932
---------- ---------- -------------

Total liabilities and
stockholders equity 9,479,940 $8,159,388 $8,118,521
========== ========== =============


Sefton Resources, Inc.
Consolidated Statements of Cash Flows

For the six months ended For the year
June 30 ended
December 31,
----------- ----------- -------------
2006 2005 2005
(unaudited) (unaudited) (audited)
----------- ----------- -------------
Cash flows from operating activities:

Net gain (loss) $175,647 $(1,008,626) $(732,464)
Adjustments to reconcile net gain
(loss) to net cash (used in) operating ----------- ----------- -------------
activities
Depletion and depreciation 82,323 98,013 199,713
Loss on fair value - 266,735 266,735
Stock issued for services - - -
Stock options issued for services - - -
Amortisation of discount on
convertible notes payable 78,463 - 38,000
Forgiveness of
accounts receivable to related parties - - 148,000
Changes in operating assets and - - -
liabilities
Accounts receivable (309,324) (81,706) (288,510)
Prepaid expenses 13,507 22,852 (5,373)
Other assets - related party (19,541) 69,687 (12,544)
Accounts payable 202,466 1,271,654 335,894
Accrued expenses - related party 19,269 (46,871) 32,187
Accrued expenses 7,368 26,859 20,988
----------- ----------- -------------
Net cash (used)
provided by operating activities 250,178 618,597 2,626
----------- ----------- -------------

Cash flows from investing activities:
----------- ----------- -------------
Proceeds from sale of oil and gas - - -
properties
Purchase of oil and
gas properties (382,766) (2,880,040) (3,314,760)
Purchase of property and equipment (26,249) (25,653) (25,951)
Establishment of
Employee Benefit Pool - (325,337) -
Acquisition of minority interest
Canada (36,484) - -
----------- ----------- -------------
Net cash (used) by
investing activities (445,499) (3,231,030) (3,340,711)
----------- ----------- -------------

Cash flows from financing activities:
----------- ----------- -------------
Proceeds from sale of
minority interest in subsidiary - - 722,071
Proceeds from notes
payable - related party - - 270,160
Payments on notes payable - related - - -
party
Proceeds from notes payable 242,005 325,337 90,820
Payments on notes payable (41,059) (140,142) (93,484)
Proceeds from sale of common stock - 459,701 -
Proceeds on private placement of
common stock 42,305 - -
----------- ----------- -------------
Net cash provided by
financing activities 243,251 644,896 989,567
----------- ----------- -------------

Effect of exchange
rate changes on cash (25,689) (1,745) (10,886)
----------- ----------- -------------

Net increase
(decrease) in cash and
cash equivalents 22,241 (1,969,282) (2,359,404)

Cash and cash
equivalents, beginning of year 126,109 2,485,513 2,485,513
----------- ----------- -------------

Cash and cash equivalents, end of
period 148,350 $516,231 $126,109
=========== =========== =============


SEFTON RESOURCES, INC. AND SUBSIDIARIES
Notes to Consolidated Financial Statements

June 30, 2006

1. The financial results for the half-year to 30 June 2006 and the comparatives
to 30 June 2005 are both unaudited. The financial information for the year to 31
December 2005 has been extracted from the full audited financial statements. The
financial statements presented in the 30 June 2006 interim statement incorporate
by reference the full audit report that is available in the Company's annual
report from 31 December 31 2005.

2. The June 30, 2006 statements do not include the Canadian Balance sheet items
in consolidation but do include the Canadian operations as a result of the sale
of TEG Oil & Gas Canada Inc. (Note 7). 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 2005 and has been approved by the Board of Directors of the Company.

3. 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.

4. On April 1, 2005, Sefton Resources, Inc. sold TEG MidContinent, Inc. to TEG
Oil and Gas, Canada, Inc. (TEG Canada) for $500,000 (United States Dollars),
2,000,000 shares of the common stock of TEG Canada and the assumption of all
future costs and expenses related to TEG MidContinent, Inc.

5. In May 2005, the Board of Directors of TEG Canada approved the issuance of
up to 6,000,000 shares of TEG Canada at a price of $0.25 (Canadian Dollars) per
share. As of June 30, 2005 subscriptions for 3,114,098 shares of this private
placement had been signed, and the Company had received cash of $459,701.

6. 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 Canadian shareholders an exchange of Sefton
shares for their shares owned in TEG Oil & Gas Canada, Inc. or repayment of
original investment As of March 31, 2006, TEG Oil & Gas Canada became a 100%
wholly owned subsidiary of Sefton Resources, Inc.

7. 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

8. As discussed in Note 7, TEG Oil & Gas Canada was sold effective May 1, 2006
and oil and gas operations costs have been included in the statements. Canadian
oil and gas production costs consist of actual figures through April 30, 2006

9. The sale of TEG Oil & Gas Canada, Inc. for cash and 100% of the shares in
TEG MidContinent, Inc. has resulted in the reporting of additional intangible
lease value derived from TEG Canada's ownership of TEG MidContinent, Inc. The
Auditors will review this transaction at year-end to ensure the accounting is in
accordance with US GAAP.

10. 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.

11. Copies of the Interim Statement will be sent to shareholders in October
2006. Copies of the Interim Statement will be available from the Company
Secretary, Pinsent Masons Secretarial Services Limited, 30 Aylesbury Street,
London EC1R 0ER.

For more information, please contact:
Jim Ellerton, Chairman and CEO Tel: +1 303 759 2700




This information is provided by RNS
The company news service from the London Stock Exchange

Looks good to me.

Sales up 306% at $1.5m

driver

PPR going well this morning ? no anything about them ?

Sales up 300% - share price down 10%

*scratches head*

smiler
No dont know anything about them 40% up on very small volume.

Harry6
Happy to hold and add on these results.

Down 20%!!!!

sells 516,000

buys 784,000

share price down 15%

*head now sore*

Hmmm . . . commiserations to anyone who bought in at the top; right now I'm glad I missed out.

PE of approx 50, mkt cap = 2 x NAV, at SP 8.4p

If I had ready cash I might take a gamble on this, but not at current SP.

WDIK, PDYOR

Here comes the buyers.

the interims were good future prospects good = share price drop-nice play-price
anfang Oct 12p i'm holding for a xmas @ eagle nest

Great results released, share price drops! WTF is going on???

Good time to top up in my opinion.