"Changing the Guard" at Buckingham Palace
is an elegant metaphor for an industry hand-over that is currently
under way in the United Kingdom Continental Shelf.
As bidders anxiously await the results of the 21st
Offshore Licensing Round -- to be announced in August -- a new generation
of E&P niche players is poised to enter the high stakes of the
North Sea and the U.K. Continental Shelf (UKCS).
For the first time in the North Sea's exploration
and production history, the stable of bidders includes numerous
small- and mid-size oil and gas companies. They've stepped up to
the plate, confident that they have the "right stuff" to win the
newly created, 24-month promote licenses from the U.K. Department
of Trade and Industry (DTI).
With more than 30 billion boe produced to date, production
peaked in the North Sea in the late 1990s at approximately 4.5 million
boed. During a 38-year run, the industry drilled about 4,000 wells,
resulting in more than 285 producing fields and another 300 plus
significant discoveries. Exploration and appraisal activity crested
the UKCS in 1990, with just over 200 exploration wells drilled.
By 2001, however, fewer than 25 exploration wells
were drilled in what was considered a mature oil and gas province.
According to the DTI, 10 major oil and gas companies
control about 80 percent of the North Sea's current daily production.
As the average pool size dwindled in the North Sea to about 30 million
barrels, the major E&P companies exited this mature oil and
gas province for "greener" exploration pastures in offshore South
America, Asia and Africa to hunt for elephant-size discoveries.
In an attempt to attract new niche players to the
North Sea -- and to arrest the projected production decline -- the
DTI introduced the 24-month promote option in February for the 21st
Offshore Licensing Round. Successful bidders have 24 months to "add
value" to the licenses -- through technical evaluations -- before
electing to continue for an additional two-year period with a prerequisite
"We recognize that this is a basin where the opportunity
is different than it was 25 years ago," says Peter Haile, DTI's
Deputy Director of Promotion, Exploration and Knowledge.
"We want to establish and promote an independent,
new tier of companies working the North Sea."
Thus, the DTI needs to tap into a new level of technical
expertise in order to exploit the remaining reserves of the UKCS,
estimated at between 25 to 30 billion boe.
Haile recognizes a full spectrum of niche opportunities
that have opened up for the smaller independents -- new fields,
undeveloped acreage, old or decommissioned fields and fallow fields.
"We want to get the licenses into the hands of the
hungry and innovative -- we're keen to realize the remaining reserves
in the North Sea," he said. "We're concentrating on new entrants."
Toes in the Water
Haile cited the Fallow Field Initiative, which forces
operators to surrender discoveries to the DTI if there has been
no work activity for four years.
In order to generate interest in the 21st Offshore
Licensing Round, the DTI teamed up with the British Geological Survey
to compile data (maps, seismic sections, well logs) to showcase
prospects, leads and undeveloped discoveries available for licensing
in the UKCS.
Thirty-eight fallow fields and/or discoveries lie
within the unlicensed acreage alone.
New players are attracted to this mature basin because
of access to infrastructure and facilities with capacity for new
product. Equally attractive is the fact that new discoveries are
royalty free. In 2002, despite tagging an additional 10 percent
to corporate taxes (they now total 40 percent), the DTI increased
the capital expenditure allowance from 25 percent to 100 percent
against general corporation tax.
Citing all of the above factors, Robertson Research
International ranked the UKCS number one in its annual "International
New Ventures Survey," published in May. Based on the confidential
polling of E&P companies, the North Sea -- with its stable regulatory
and fiscal regime -- was the top pick for new ventures in 147 countries
outside of North America.
As the average pool size declines, Haile explained,
"value must substitute for volume; the UKCS is competitive and offers
an attractive environment for business.
"If the opportunity is small, in order to make money,
then you must move very quickly," he added.
"We've seen a basin go from discovery to decline
... in one person's career," said Stephen Greer, president and CEO
of Calgary-based Antrim Energy.
Greer, however, would be very content to find an
average-size, 30 million-barrel-field in the North Sea. Antrim is
a junior oil and gas company that focuses on high-risk, high-reward
international targets in the North West Shelf of Australia, offshore
Tanzania, Tunisia, Argentina and the Czech Republic.
Antrim also is familiar with the DTI, as it operates
the South Larne License in onshore, Northern Ireland.
With production of just over 400 boed, Antrim is
listed on the Toronto Stock Exchange with a market capitalization
of about $C16 million. Greer, an AAPG member, says that the 24-month
promote license has enabled Antrim and its partner to compete head-to-head
with much larger companies for several offshore licenses.
The 24-month promote licenses form one component
of Antrim's three-prong growth strategy in the North Sea. Antrim
also is currently negotiating the acquisition of a producing field,
and is proceeding with a secondary listing on the London Exchange's
Alternative Investment Market to access U.K.-based investors.
"The 24-month promote licenses enable us to dip our
toe into the North Sea before jumping in," Greer said. "It's a tremendous
advance for the U.K."
Looking for the Right Stuff
As the name suggests, the DTI anticipates that many
of the smaller companies will "promote," or farm out, the blocks
prior to proceeding with the work commitment phase, which will include
the drilling of at least one well or the conduct of an equivalent
agreed, substantive activity.
Equally attractive for small players is the cost
of entry for the 24-month promote: the DTI slashed the license rentals
per square kilometer from £150 for a traditional license to £15
for a promote license. A block consists of approximately 220 square
kilometers; licenses are comprised of one or more contiguous blocks.
In June, the DTI conducted interviews to qualify
potential bidders for the 24-month promote licenses. Reminiscent
of the questions posed on a first date, the DTI had a shopping list
of prerequisites for the second date.
In other words, the companies had to possess the
"right stuff," including technical acumen, new ideas and geological
concepts, and the wherewithal to carry out the proposed 24-month
"The DTI is sophisticated -- they can look you in
the eye and tell whether you've got the technical ability to add
value to the block," Greer said. "They're opening the door -- not
everyone with the understanding of the North Sea has the financial
ability to work there."
Bob Welty, chairman and CEO of Calgary-based Sterling
Resources, concurs with Greer.
"It's your chance to show them what you can do --
you have to present your credentials," Welty said.
Indeed, the interview process enabled Sterling's
team to present new geological concepts, analogs and technologies
to the DTI for two licenses.
"Even though we're not a major, we can bring experience,"
No stranger to the international arena, Sterling
holds licenses in Romania and in the Wessex, Weald and Cleveland
sedimentary basins onshore U.K. Currently without production, this
junior oil and gas company trades on the TSE Venture Exchange with
a market capitalization of about $C9 million.
Sterling, in conjunction with partners, has applied
for two offshore promote licenses, intending to operate one of the
two. One license is 2.5 blocks in size, the other 3.0 blocks.
"This was an opportunity for us to enter the offshore
sooner than we thought possible," Welty said.
Who Will Farm-In?
On the flip side, given that the majors are leaving
the North Sea, how will the small- to mid-size E&P companies
farm out their blocks in two years' time?
"The bigger issue," cautions Keith Skipper, Antrim's
executive vice president and an AAPG member, "might become who will
finance the farm-in wells? The capital markets are the ultimate
key here, and they are not very supportive of exploration at the
Antrim however, expects to finance its own offshore
Tailored to the needs of those small- to mid-size
companies who win the 24-month promote licenses, APPEX London will
provide new venue for explorers to showcase their properties. APPEX
London is AAPG's international Prospect and Property Expo, and it
will be held March 2-4, featuring a three-day upstream business
conference focusing on international E&P opportunities.
Steve Veal, AAPG's European regional consultant who
is part of the organizing team for APPEX London, expects that the
winners of the 24-month promote licenses will be exhibiting their
prospects at APPEX.
"The DTI has essentially opened the doors for small-
and mid-size companies," Veal said. "Until now, the North Sea has
been a 'big boy' play.
"It's a great campaign to revitalize a national oil
and gas industry," he added. "It's going to spawn a whole new breed
of independents in the U.K."
To date, 88 percent of the North Sea's discovered
fields consist of conventional, structural traps; the more subtle,
stratigraphic traps constitute only 5 percent of producing fields.
The remaining 7 percent of the producing fields are
of a combined structural-stratigraphic nature.
"The capability of finding big discoveries is still
out there," Veal continued. "All the giants of the North Sea have
not been found."
The discovery of the Buzzard Field in 2001 by North
Sea-newcomer PanCanadian Energy Corporation, proves that elephants
can often lie just beneath your nose. It also proves that there's
still significant life (reserves) left in the North Sea.
Calgary-based EnCana Corporation, North America's
largest independent, currently operates the Buzzard Field. With
1.1 billion barrels of light oil in place, Buzzard represents the
biggest find in the North Sea in more than 20 years.