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See amendments, "Energy
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of 2001 (Draft)" &
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text version; U.S.
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Report on the Alaska Natural Gas
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Commission, 1-18-01
ALASKA:
1-23-03,
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2002 DRAFT Recommendations to 2003
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'02 Alaska Legislation;
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Joint
Legislative Gas Pipeline Committee; 9-01 Alaska Models:
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HR 4 Story;
Cook Inlet Supply-Demand Report:
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Commonwealth North Investigation
&
Our Article;
Report: Backbone;
Legislature Contacts;
State Gas Pipeline Financing Study;
5-02 Alaska Producer Update;
Kenai: "Oil & Gas Industry Issues
and Activities Report, 11-02";
Alaska Oil & Gas Tax Structure;
2-27-02 Royalty Sale Background;
Alaska Gas Pipeline Office
opens, 7-01, and
closes, 5-02;
Betty Galbraith's
1997-1998 Chronology.
Our copy.
CANADA:
1-10-03, "Arctic Gas Pipeline
Construction Impacts On Northern Transp."-Transport Canada-PROLOG Canada
Inc.-The Van Horne Institute;Hill
Times Reports, 8-30-02;
9-30-02, Cons. Info. Requirements;
CBC Archives, Berger Commission;
GNWT Economic Impact Study,
5-13-02;
GNWT-Purvin & Gertz Study, 5-8-02;
Alberta-Alaska MOU 6-02;
Draft Pan- Northern Protocol for
Oil and Gas Development;
Yukon Government Economic Effects:
4-02 &
PPT;
Gas Pipeline Cooperation Plan
Draft &
Mackenzie Valley Environmental
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Mackenzie Valley Pipeline MOU
Draft, 6-01;
FirstEnergy Analysis: 10-19-01;
Integrated Delta Studies;
National Post on Mackenzie
Pipeline, 1-02;Northern
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Haida
Nation v. British Columbia;
Indian Claims Commission;
Skeena Cellulose decision --
aboriginal consultations required, 12-02;
Misc. Pipeline Studies '02
COMPANIES:
Alaska Gas Producers Pipeline Team
Newsletter, 7-27-01;
APG Newsletter: 5-02,
7-02
&
9-02;
ArctiGas NEB PIP Filing Background;
NRGPC Newsletter: Fall-02;
4-02 ArctiGas Reduces Field Work;
BP's Natural Gas Page;
Enbridge Perspective;
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MEDIA
REFERENCE: Alaska Journal of
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LEST WE FORGET!
| |
Alaska Gas Pipeline Related
Works of Joe LaRocca
11-12-76,
Alaska Natural Gas Transportation Act of 1976 Passed
11-19-76, El Paso, Tenneco and Southern Gas to Get State
Royalty Gas
11-26-76, What Royalty
Gas Agreement?
03-18-77,
Gas Sales Contracts
03-30-77, Gas Sale Backfires
03-31-78, North
Slope Producers May Pre-empt Gas Liquids Use
09-05-80,
Interior Dept. Calls for Major Changes in
Gas Pipeline Route
03-06-81, North Slope Gas Conditioning Plant
10-08-82,
CO2 Content is Key to Economic
Viability Of All-Alaska
Gas Pipeline
10-29-82,
Gas Pipeline an Example of
U.S. Energy Policy ‘Gone Haywire'
2004, “Alaska
Agonistes" and many other works
05-06-05, "'Hubbert's Peak' oil thesis is deeply flawed"
November 12, 1976, The All-Alaska Weekly
Law
passed to speed up gas line authorization
A little-publicized provision of the Alaska gas pipeline act signed
into law recently by President Ford would enable the builders of a gas
pipeline to draw on federal funds to finance its construction if they can't
obtain enough money from the private sector.
The
act - better-known for features designed to speed up the authorization and
construction of a gas pipeline and allow the State of Alaska to withdraw its
royalty gas for use within the state -also contains a number of other major
provisions which have received little or no public discussion. It is only the
second law in U.S. history passed by congress to authorize the construction of
a pipeline. The other was the Trans Alaska Oil Pipeline Act of 1973.
It permits, for example, the export of Alaska's North Slope gas to Mexico
and Canada, and authorizes the president to approve exports to foreign
countries if that would not diminish the quantity or quality, nor increase the
cost of, energy to U.S. consumers.
The act also directs the U.S. Attorney General to undertake a thorough study
of anti-trust issues and problems relating to the -production and
transportation of Alaska natural gas, and submit its findings and
recommendations to Congress by next Spring.
And it requires the President to furnish Congress with an analysis of the
financibility of a transportation system for North -Slope natural gas. Unless
the president finds in his report that he reasonably anticipates
that the system he favors can be privately financed, constructed and operated,
he must also include his
recommendations concerning the "use of existing Federal funding authority or
the need for new federal financing authority."
This requirement conveys the concern felt in some quarters that the
enormous cost escalations experienced in the construction of the trans Alaska
oil pipeline, now approaching $8 billion, may be repeated in the construction
of the gas system, whose
initial estimates range from $4 to $8 billion. Any escalation in its cost
could drive the project beyond the financial capability of the private
sector, and require governmental assistance.
Another curious provision which found its way into the gas pipeline act is
embodied in a section which requires the president to determine and report to
Congress on what procedures are necessary to guarantee that North Slope crude
oil is equitably allocated to the so-called Northern Tier States. These
include Washington, Oregon, Idaho, Montana, N. Dakota, Minnesota, Michigan,
Wisconsin, Illinois, Indiana and Ohio.
This section was written into the gas act at the insistence of congressmen
from those states who discovered belatedly that earlier industry assurances
that construction of the trans Alaska oil pipeline would not result in a
excess of oil on the U.S. West Coast, were false.
These congressmen reluctantly supported the trans Alaska oil line in 1973
rather than the proposed trans Canada line because of industry claims that
the Alaska line could be completed more quickly, and reduce the nation's.
dependence on imported oil sooner during the emerging "energy crisis" of
1973.
Now
they have learned that there will be a large surplus of North Slope oil on the
West Coast which may be exported to Japan, and they are now seeking to devise
a means of transporting the excess crude to their own energy-short states
instead. Their support for the gas pipeline act was dependent upon the
inclusion of this section in it.
Among other things, the so-called "procedural act" directs the president
to compete his study and report on a Northern Tier oil transportation system
within six months after the effective date of the gas act. It also requires
all federal officers and agencies to expedite any applications and requests
relating to the construction of a transportation system designed to carry
North Slope crude oil to the Northern Tier states.
Officially entitled the "Alaska Natural Gas Transportation Act of 1976,"
the new federal law is more commonly called the "procedural act" because it
spells out in precise terms the administrative process and timetable which
are to be followed in selecting and authorizing a gas transportation system
for North Slope gas. Now that the president has signed the act, the Federal
Power Commission (FPC) has until May 1 to submit its recommendations to him on
which of three proposed routes, if any, the FPC believes should be built,
regardless of whether the Canadian government has authorized the construction
of a pipeline system to transport Alaska's natural gas across its territory.
The FPC's recommendation must contain a description of the nature and
route of the system it sanctions and designate which applicant should
construct and operate it. Which ever system the FPC recommends must include
provisions for any new facilities necessary to assure "direct pipeline
delivery of Alaska natural gas contemporaneously to points east and west" of
the U.S. Rocky mountains. Its recommendations must be
accompanied by a public report explaining the basis for its choice, and
discussing a series of factors relating to each transportation system that was
considered. These include:
- the estimated volumes of Alaska natural gas which would be available to
each region of the U.S., along with the transportation cost, delivered price,
and effects on each region's projected gas supply and
demand, by year through 1997;
- the extent to which the system provides a means of transporting other
natural resources and commodities to lower U.S. markets;
- safety and efficiency in design and operation of the system, along with
the potential for interruption in the delivery of gas;
- construction schedules, and the possibility of delays in achieving
them;
- the extent of both proven and probable reserves in Alaska, and their
deliverability, by year through 1997;
- the cost and capability for expanding the system to carry volumes of gas
which exceed initial system capacity, and
- an estimate of capital and operating costs, and possible overruns.
The FPC must also submit to the president along with its report, an
Environmental Impact Statement (EIS) on the recommended system, and another
EIS it may have prepared on any alternate system it considered. Between now
and its May 1 deadline, the FPC may continue to hear arguments and testimony
on behalf of, or in opposition to, any of the pipeline systems under
consideration. During the following two months ending on July 1, 1977, any
interested party, including any federal agency, state or municipality can
submit written comments to the president concerning the FPC's recommendations
and report.
During the same period, the federal Council on Environmental Quality (CEQ)
must hold public hearings to take oral and written testimony on the FPC's
recommendations and report, and submit to the president by July 1 its findings
concerning the sufficiency of the FPC's environmental impact statement.
Anytime after July 1, but no later than
Sept. 1, the president is required to issue his decision on whether the FPC's
recommended system, or any other one, should be approved. There is, however, a
provision for extending the president's decisional deadline by up to 90 days
if an EIS has not been prepared for the system he chooses; if he feels the
EIS for the system he has chosen is inadequate, or if additional time is
needed to enable him to reach a "sound decision."
While it's assumed that the president will select some pipeline system,
the act also gives him the option of deciding that no system should be built.
If he decides to designate a system for approval, the president must at the
same time describe the route, specify which applicant should build the system,
identify what existing laws must be waived to expedite construction of the
system, and appoint an officer or board to serve as "Federal Inspector of
Construction," subject to the advice and consent of the Senate.
The federal inspector, a cabinet-level official, is empowered to establish
a joint surveillance agreement with the state of Alaska to monitor gas
pipeline construction, enforce compliance with the terms of any permits,
certificates or other authorizations issued to the pipeline builders, and
oversee actions designed to assure timely completion of construction schedules
and to achieve quality of construction, cost control, safety and environmental
protections.
Following the president's decision, which may come on or before Sept. 1,
or as late as Dec. 1, of 1977, Congress has given itself 60 days to pass a
joint resolution approving the president's decision. If Congress has not
acted by the end of 60 days, or if one or both houses has defeated the
resolution, the president has another 30 days to submit an alternate decision
which must differ "in material respect" from his previous
one.
Congress has also provided in the act means of preventing its members and
committees from delaying action on the resolution encompassing the
president's decision. If any committee to which the resolution has been
referred fails to report it out
within 30 days, the measure can be discharged from committee, with debate on a
motion-to-discharge limited to one hour.
After the president's decision has been submitted to the congress, both
the FPC and the CEQ have 20 days to file reports with Congress containing
their comments on the president's decision. Both agencies, as well a the
congressional committees considering the bill, must hold public hearings on
the various subsidiary reports dealing mainly with environmental
considerations.
After the resolution has been moved or discharged to the floor of either
the House or Senate, any motion to consider it is not debatable. Once under
consideration, debate on the resolution itself is limited to ten hours,
divided equally between those favoring and those opposing it. The resolution
cannot be amended, re-committed to committee nor - once a vote on it has been
taken - reconsidered. The resolution must contain a finding by the president
that the gas transportation system he approves is fully in compliance with the
National Environmental Policy Act of 1969.
Once the resolution is approved, any permits, certificates, rights-of-way
or other authorizations needed to undertake construction of the pipeline
system must be issued "at the earliest practicable date." None of the terms or
conditions of these authorizations may include provisions which would "compel
a change in the basic nature and general route of the approved transportation
system," nor prevent nor impair” its "expeditious construction and initial
operation."
Under the act, only two types of legal claims are subject to remedy in the
courts: one, that the act itself is invalid on constitutional grounds, and
two: that actions authorized by it infringe on constitutional rights or are
beyond the authority of statutory law. The validity of the act may be
challenged only within 60 days after the president submits his decision on the
selection of a gas transportation system to the Congress.
And claims that actions taken under the act deny or infringe upon
constitutional rights must be raised within 60 days after the action has
occurred. Any court proceeding under the act must be given precedence over all
other matters on the docket, and completed within 90 days. Violation of the
act, or non-compliance with any rules or regulations stemming from it -
including the terms and conditions of permits, rights-of-way or other
authorizations granted pursuant to it - are subject to civil action, including
court injunctions or a civil penalty of $25,000 for each day of
non-compliance.
The act includes a common carrier provision guaranteeing any shipper of
North Slope natural gas access to the transportation system under the same
rates and conditions which apply to any other shipper, including the system's
owner companies. The same section contains the provision authorizing the State
of Alaska "to ship its royalty gas on the approved system for use within
Alaska and to the extent its contracts for the sale of gas so provide, to
withdraw such gas from the interstate market for use within Alaska."
Lastly, there is a civil rights provision requiring federal operatives to take
whatever action is necessary to assure that no one is excluded from employment
on the transportation system because of minority traits.
March 18, 1977
- Politics endanger state's royalty oil
The Hammond administration's single-minded preoccupation during the past year
with its politically-inspired scheme to sell all of the state's royalty gas
from Prudhoe Bay has indefinitely deprived the state of its right to take its
royalty oil for in-state use, or any other purpose.
Unless the North Slope
producers voluntarily agree to foreshorten the six-month notice period
provided in the state's oil and gas lease contracts for taking its royalty oil
in-kind, the state is in the awkward position of having both forfeited its
ability to take the oil in-kind and committed it to interstate commerce, from
whence it shall never return.
These unfortunate
circumstances arise from obscure regulations issued by the Federal Energy
Administration during the
Mideast oil embargo of 1973. Among other things, they
prohibit suppliers of crude from terminating any contracts with purchasers of
the crude without the consent of the purchasers and their buyers further down
the line.
Moreover, FEA administrative
law has interpreted the taking of royalty oil in value as a first sale by the
state to the producer, which means that it cannot later be taken in kind,
without the express consent of the producer.
When the effect of the FEA
regulations under the Mandatory Petroleum Allocation Act initially came to
light here recently with respect to the state's royalty oil, it was assumed
that only the royalty oil not taken in-kind during the required six-month
notice period provided in the lease would be forfeited by the state.
But more recent information
now suggests that the producers' claim to royalty oil not taken in-kind - as
a result of the state's failure to give timely notice - can be automatically
extended to include all of the state's royalty share of incremental
production. This would rise to 150,000 bpd of royalty oil as the initial
flow of oil through the trans-Alaska pipeline is increased in accordance with
the leaseholder's production schedule and the pipeline's operational
timetable.
In short, the producer's
authority to keep the 70,000 bpd royalty oil which the state has already
forfeited, based on initial total production of 600,000 bpd, can be
unilaterally extended by the producers to claim the 150,000 bpd or more of the
state's royalty share stemming from total daily production of 1.2 million, and
beyond. as production volumes rise.
Because the administration
and the legislature have allowed themselves to be stampeded by special
interests into devoting their efforts exclusively to the sale of
Prudhoe Bay royalty gas for political leverage to the
exclusion of other equally important concerns, the state now faces the real
prospect of losing both its royalty oil and gas to export markets.
This double dilemma results
from the state's misplaced focus upon the royalty gas question, based on the
dubious - and rapidly eroding - assumption that commitment of the gas at this
time would politically facilitate the selection of El Paso's all-Alaska gas
pipe - line project by federal authorities who hold jurisdiction over more
than half the proposed pipeline's right-of-way. Equal or greater attention
should have been directed to the question of the disposition of the state's
royalty oil at least a year earlier.
Oil production at
Prudhoe Bay is imminent, perhaps three to four months
away, in test volumes. The production of natural gas there, on the other hand,
is four to six years removed, or longer. Thus the state is in the absurd
position of having committed its royalty gas too soon, and its royalty oil too
late, simply because it failed to observe - for purely political reasons - the
elementary rule that first things come first. These reverse miscalculations
both have the same dire result: they preclude the state from being able to
claim either its royalty oil or gas for in-state use, unless the FEA revokes
the rule.
It's possible that the state
may be able to negotiate a trade-off agreement with the producers whereby they
would consent to a belated in-kind taking of its royalty oil by the state. But
one can be sure that the concessions the state must make in such an exchange
won't come cheaply.
Before he left for
Washington, D.C. last week, outgoing Commissioner of Natural Resources Guy
Martin, who has been the state's chief functionary in the execution of the
royalty gas fiasco, wrote letters to all of the
North Slope producers asking them if they would
voluntarily foreshorten from six months to one the notice period which the
state must observe in taking its royalty oil in-kind.
At the same time, Martin
asked the chief spokesman for the
North Slope producers in the on-going unit operating
agreement negotiations to seek approval from the producers for the insertion
of a similar provision in the pending unit agreement.
At this writing, Martin's
successor, acting Commissioner Jack Roderick, reported that so far only two of
the
North Slope producers have responded to Martin's
request. One, Phillips Oil, said it had already committed the state's
royalty oil from its share of production to a refiner, while Amerada Hess said
it would have a detailed response shortly. BP/Sohio, Arco and Exxon have not
responded to date.
3-30-77 Governor Hammond’s gas sale
blunder backfires
Although the magnitude of its folly has not yet been generally recognized
by the public-at-large, the
Hammond administration's abortive scheme to
exploit the state's enormously valuable royalty share of natural gas
production from
Prudhoe Bay for purely political gain ironically ranks
at the top of the governor's numerous political blunders to date.
A further irony is that the scheme's principal architect,
former Commissioner of Natural Resources Guy Martin, has not only
escaped the ill consequences of his role as the leading, most articulate
advocate of the foredoomed contracts, dumping them unceremoniously into
the laps of his former boss and colleagues; he has at the same time managed
to parley that and other dubious achievements of his brief state tenure into a
plush and prestigious federal sinecure for himself as an assistant secretary
in
the U.S. Interior Department.
For it was Martin who almost single-handedly devised and
executed the Hammond administration's irrational plot to sell all of the
state's surplus royalty gas from Prudhoe Bay to three major pipeline
companies in exchange for their political support on behalf of the El Paso
Co.'s now-defunct proposal for an All Alaska gas pipeline, which
Hammond mistakenly perceived as the routing alternative most likely to
enhance his re-election prospects in 1978, and the one to which he therefore
threw his wholehearted support.
Now that both the El Paso project and the royalty gas sale
contracts have exploded in his face, Hammond faces the unenviable task of
attempting to defend his past actions, while at the same time acknowledging
their failure by taking steps to repair or minimize the extensive damage
they have wrought upon both his personal political aspirations and the
integrity of state public policy. While Guy Martin deserves most of the
credit for misleading
Hammond along the path of political fatuity,
he
doesn't deserve it all.
Some must be reserved to Hammond's other leading policy
advisor, Attorney General Av Gross, a nice guy, but an inept attorney
general whose appointment to that position eloquently pleads the argument
in favor of elected attorneys general by demonstrating the hazards of
substituting for them political flunkies.
More specifically, one of the lesser, but readily apparent
adverse effects of Hammond's politically-inspired proposal to sell the state's
royalty gas to El Paso, Tenneco and Southern Natural Gas was its wholesale
disruption of the 1977 legislative session, which was almost exclusively
pre-occupied for more than a month with matters relating directly to the
proposed gas sale contracts. If there is a single reason why the 1977
legislature broke all records for the length of a First Session it was, of
course, its exhaustive preoccupation with the gas contracts, whose imminent
dissolution concurrent with the predictable demise of the El Paso project
accentuates both their inherent futility, and the valuable time lost and
motion wasted which might have been spent more productively on truly
urgent and viable legislative matters.
Not to mention the thousands of costly man-hours which
industry executives, administration aides and officials, as well as the State
Royalty Oil and Gas Advisory Development Board, devoted to the lengthy
negotiations and reparations leading to the ultimately worthless gas sale
contracts.
Even
more harmful to the interests of Alaskans was the
Hammond administration's inexcusable -
bordering on criminal - neglect of the state's royalty oil from
Prudhoe Bay. In his anxiety to cement his 1978
re-election prospects, Hammond ordered a crash program in early 1976 designed
to commit the state's royalty gas, worth billions, to bidders who, as a
condition of securing the gas, would agree to lobby on behalf of the El Paso
pipe-line project, despite the fact that the state's royalty oil from
Prudhoe Bay would be produced years before its gas would become
available.
As a direct consequence of its premature
preoccupation with
the politically-conceived royalty gas deals, the Hammond administration
ignored the critical need to provide for the timely disposal of the state's
valuable royalty oil concurrent with the completion of the trans-Alaska oil
pipeline, and is even now up to a year away from making the state's royalty
oil available for processing and use within the state.
Moreover, Hammond's delay in claiming the
state's royalty oil
in-kind led to the still-imminent danger that some or all of the royalty oil
may be committed irrevocably to out-of-state use under the Federal Energy
Administration's crude allocation regulations, thus making it unavailable for
in-state use.
November 26, 1976,
The All-Alaska Weekly
What royalty
gas agreement?
By JOE LaROCCA
Last week, in a half-hour statewide address, Governor Jay
Hammond announced his proposal to sell most of the state's royalty
share of prospective
North Slope natural gas to three major pipeline
transmission
companies, El Paso Natural Gas, Tenneco and Southern Natural Gas.
There's an old
speechwriter's rule that if you say something
artfully, it doesn't much matter what you say.
Hammond's speech hewed
closely to that rule. It was one of his more stylish speeches, which
suggests
that someone else wrote it. Its high style may have blinded casual observers
to its dearth of substance.
All the weapons of the
propagandist's arsenal were brought to bear. His speech was riddled with
subtle misrepresentations, misleading nonsequiters, distortions,
half-truths, demagoguery and outright - there is
no other word for it - lies. For example, the governor said that in arriving
at his decision to support
El Paso's proposal for a trans
Alaska gas pipeline, "It would have been
easy to simply hop on to the all-Alaska bandwagon at the outset of my
administration, since that route was obviously most popular with most
Alaskans." Instead," he said, "we had to study the facts and come to an
unbiased, supportable conclusion.
“ I therefore created a
high-level group to study the proposed alternate routes for the pipeline,"
which ultimately concluded that the
El Paso route "would bring the most
greatest benefits to the state in the long run." What he neglected to say
was that it would also bring him the most votes in his upcoming bid for
gubernatorial reelection.
A ranking sub-cabinet staff member close to the discussions
told me later that the governor's "high-level" study group privately
met three times briefly, only to hear pitches from
the proponents of the three pipeline
routes, with no input from opponents or critics. Its creation was a
charade designed solely to lend credibility to a ritual agreement
endorsing a pre-ordained political decision to
support the
El Paso route in order to serve
Hammond's reelection aspirations, the
source said.
A major advantage of the El Paso route, the governor said, is its
potential for "maximum use of the existing (oil) pipeline corridor
(which) permits beneficial usage of the enormous
amount of environmental,
construction and engineering data gathered in the building of the trans
Alaska (oil) pipeline." But he ignored the fact that the same rationale applies, in spades, to
Northwest Pipeline's proposed Alcan route, which would not only follow the
oil pipeline as far as Delta Junction, but would also parallel the Alaska
Highway and the Haines petroleum products pipeline corridor through Alaska
and Canada, unlike the final 100 miles or so of the proposed El Paso line,
which would traverse relatively untouched terrain in Alaska.
Further, the governor
said, "The trans
Alaska route will also
provide the maximum revenue for the state primarily because of the
large property tax base it would create within our
borders.'' But neither the governor nor his
alleged "study" group and costly consultants have
yet quantified the ultimate costs of the El Paso route
to include the necessary development or retrofitting of a system for
distributing the gas from West Coast seaports eastward to distant
markets in the U.S. south, and their impact upon
the wellhead value on which the state's severance
tax revenues depend.
Nor had they included the
cost of building a new fleet of cryogenic, or refrigerated tankers to carry
the liquefied gas from a southern
Alaska port to receiving sites on the
U.S. West or
Gulf
Coasts. Under
Hammond's proposal, the state would buy,
own and operate the liquefied gas ocean tankers, the cost of which has also
not been calculated.
Thus, the governor's
statement that the
El Paso route would maximize revenues to
the state is, at best, insupportable and, at worst, untrue. Contrary to his
assertions, the
El Paso line is not now demonstrably
superior to the Alcan route, from either an economic or environmental
standpoint, but is more likely inferior to it.
Hammond said that as soon as the third
pipeline route proposal advanced by Northwest
Pipeline surfaced "we directed the same attention
to the Alcan route as we had to the two previous
route proposals." Wrong
again.
As I've pointed out
before, shortly after Northwest first announced
last Spring that it might apply to the Federal Power Commission for an
Alcan routing, the governor was quoted by the Anchorage Times as
saying that "the state has done its own
preliminary study of a natural gas pipeline route
down the
Alaska Highway. Based on the available information,"
he said, "our indications are that it is not
economically feasible."
In fact, no study of the
Alcan route had been undertaken by anyone in his
administration, various
Hammond appointees - including his
press secretary - later admitted to me when my own research could
find no
evidence of one. The governor had concocted an illusory study out of thin
air.
It wasn't until later,
after substantial support for Northwest's Alcan route
had materialized both inside and outside
Alaska, that public opinion
prodded the
Hammond administration into undertaking a
study of that
alternative. Since then, the governor has been forced to re-trench
considerably, and he now wants "to make it clear, however, that the
Alcan proposal is a good second choice."
That sounds suspiciously
like a knee-jerk response to U.S. Senator Ted Stevens' recent admonition to
Alaskans not to bad-mouth the Alcan proposal, in the event the federal
government rejects El Paso's route, thus compelling Alaskans to support the
Alcan route as an alternative to the Arctic Gas' proposed trans Canada
route, which is political anathema to the governor
and his fellow chauvinists.
The governor's lengthy
justification on the air of his decision to
support the
El Paso route was a preamble to his
detailed rationale supporting his ensuing decision
to sell most of the state's royalty gas from
Prudhoe Bay to
El Paso, Tenneco and Southern Natural Gas.
The proposed sale, which
requires legislative approval, was mainly a means
of gaining political support at the federal level through
lobbying by the three companies for the
El Paso route, he said. Another
"important reason why we should move now on a sale," he added, relates to
the amendment recently passed by Congress which purports to allow the
state to withdraw its royalty gas from whichever pipeline is built
for domestic and industrial use within the state,
if needed. The Congress had granted no other state
that privilege.
Without divulging his
source nor confirming its authenticity,
Hammond told his statewide audience he has
"been informed that an attempt will be made next
year in Congress to repeal" that provision, thus
making it "prudent now to conclude an arrangement for sale of the gas while
the law is fully in effect."
That's rumor-mongering of
the worst sort, which raises the suspicion that
the governor may be floating a red herring in order to create a
false sense of urgency. There was absolutely no suggestion during the
final
debate in Congress on the amendment, of any opposition to it. Alaskans
should demand to know the source of the governor's "information," so
that they can evaluate its validity. Hammond, who
often upbraids the news
media for utilizing anonymous sources, rendered himself susceptible to his
own criticism.
Hammond said his proposed gas sale
"appears to have widespread support throughout the
state," and that "No firm voice has been raised in opposition to such a
concept for many months." While there is no opposition to the "concept" of a
sale of the state's royalty gas, that obviously doesn't mean that everyone
approves of the governor's current proposal to sell it in accordance with
his specifications. In fact, there is widespread and vocal opposition to it.
He noted that the proposed sale agreements
are "a tentative contract" which must be submitted first to the state
royalty board, and then to the legislature for approval, thus implying that
the board's approval may be in doubt. In fact, the board - which was meeting
in
Juneau on Monday to consider the
governor's proposed sale - was sure to rubber-stamp it.
Indeed, one member of the
board accompanied Natural Resources Commissioner
Guy Martin on a quiet overnight trip to
Fairbanks last week to attempt to
persuade recently-appointed board member Andy Warwick of
Fairbanks of the
merits of the proposed sale and support it. Warwick, a former state
legislator and commissioner of administration under
Hammond has publicly
criticized the governor's proposal
Hammond said the contract "builds in a
clear incentive" for the three purchasers to
support the
El Paso line "by providing that the sale
will be terminated if the route supported by the
state is not the one eventually
selected for transportation of the gas."
But at
the same time, he said that "If the state decides at some future time to
support a different route than the trans
Alaska route, the buyer under the
contract will have the option of supporting this new route or in the
alternative, losing its right to the gas.
As I've noted previously,
it matters little to the three purchasers -
particularly Tenneco and Southern Natural Gas, who together would
receive three-fourths of the state's royalty gas from Prudhoe Bay -
which
pipeline route is selected, once they've obtained a commitment from the
State for its royalty gas, which is their major objective. They
would have few, if any, qualms about switching
their support to whichever pipeline
route is authorized by the federal government.
But the governor's most
salient misrepresentation of this so-called royalty gas sale agreement was
his failure to note that it's so riddled with opt-out provisions that any
party to it can abandon it with impunity under virtually any set of
contrived circumstances.
November 19, 1976,
All-Alaska Weekly
El Paso, Tenneco and
Southern Gas to Get Royalty Gas
Gov. Jay Hammond's unsurprising announcement last weekend that his
administration had negotiated agreements to sell the state's North Slope
royalty gas to three companies in exchange for their support of an All Alaska
gas pipeline route, represented a triumph of public relations over rational
public policy.
The hoopla that attended his
announcement effectively concealed from most observers the fact that, with the
stroke of a pen,
Hammond signed away a precious state asset
and got nothing, or less, in return. Fortunately, the buck doesn't stop at
Hammond's desk. The agreements are subject
to legislative approval, which guarantees a more public - perhaps even sane -
approach to the disposal of the state's
Prudhoe Bay royalty gas.
Hammond's capitulation to the overt
pressures of vocal and influential special interests was painfully reminiscent
of the pre-OPEC era when gullible
Middle East monarchs gleefully collected baubles from
shrewd entrepreneurs in exchange for oil concessions worth billions.
There are at least two major
reasons why
Hammond's artless dealings with the three
tentative purchasers of the state's royalty gas - were they final - would
profitlessly deprive the state and the majority of its citizens of an
enormously valuable asset. First, his premature commitment of a portion of the
gas to the El Paso Co. renders that company's plan for an All Alaska pipe-line
academic, since its real - if covert - motive was mainly to nail down a
substantial share of
North Slope natural gas.
Although El Paso will
continue to pursue its pipeline proposal publicly in order to maintain the
appearance of a good faith effort on behalf of an All Alaska line, if the
legislature ratifies the governor's agreements it would matter little to El
Paso whether its own or a competing pipeline route is certified by the federal
government.
It's also irrelevant to the
other two purchasers - Tenneco and Southern Natural Gas - who agreed to
support and lobby for the
El Paso proposal in exchange for a share of
the state's royalty gas - which pipeline system is built, since they too would
be guaranteed a major share. But in order to appear to live up to their end of
the bargain, they will lobby overtly on behalf of
El Paso's proposed All Alaska pipeline.
Under the agreements, all three could retain their rights to the state's
royalty gas if a route other than
El Paso's is selected, simply by switching
their support to whichever project wins federal approval.
Secondly, the national
political realities - reinforced by President-elect Jimmy Carter's recent
victory - guarantee the certification by the federal government of Northwest
Pipeline's proposed Alcan route, now the only politically-viable alternative
to the trans Canada route proposed by Arctic Gas.
The Arctic Gas proposal has
been effectively foreclosed by a series of adverse events, which include the
Berger Inquiry's recent staff report concluding that the resolution of native
land claims in
Canada - 10 to 15 years in the
future - is a prerequisite to the construction of any pipeline through the
Canadian arctic.
While that portion of the
staff report was widely-publicized by
Alaska's pro-EI Paso news media and
political establishment, little was said about the Berger staff's concomitant
conclusion that Northwest's Alcan proposal would not adversely conflict with
Canadian natives' unsettled land claims.
And to the extent that the
claims issue is a factor in the certification of the Alcan route, Northwest
scored a shrewd coup when it captured Morris Thompson as its
Alaska project director, whose
Alaska native origins and recent experience
as head of the U.S. Bureau of Indian Affairs in
Washington provide a strategic advantage.
Arctic Gas' cause has been
further prejudiced by the unexpected failure of explorationists to find
sufficiently commercial quantities of gas in the Canadian arctic, upon which
the economic feasibility of Arctic Gas' proposal depended.
These critical factors,
which preclude any need for the State to commit its royalty gas to anyone -
and which were effectively masked by yet another administration "study"
purporting to establish the economic superiority by El Paso's proposal - were
conveniently overlooked or ignored by the governor in the interests of
furthering his recently-disclosed intentions to run for re-election in 1978,
which he has loudly denied
for the past couple years.
From The All-Alaska
Weekly,
September 5, 1980
Interior Dept.
Calls for Major
Changes in
Gas Pipeline Route
By JOE LaROCCA
Responding to widespread criticism that the sponsors of the proposed
$23 billion Alaska Highway Gas Pipeline Project are ignoring vital concerns of
the state and others, the U.S. Interior Dept. has approved a rights-of-way
grant over federal lands in Alaska which makes what one top official says are
“significant departures “ from the initial routing proposed by Northwest
Alaskan Pipeline Co.
Dr. Charles Behlke, state pipeline coordinator, says the new
alignment adopts a 200-foot separation between the proposed gasline and the
existing trans
Alaska oil pipeline which is more than
double the 80-foot separation initially proposed by Northwest.
It also includes an option for punching a two-mile tunnel through
Atigun Pass in the
Brooks Range, instead of laying the pipeline over the top of the pass, Behlke
said, a construction strategy which caused the oil pipeline to collapse after
it was completed.
The rights-of-way grant was approved by the Interior Dept. on August
20, then submitted to Congress for review as required by aw, although – a
former state commissioner of natural resources - has asked U.S. Senator
Henry (Scoop) Jackson D-Washington, and other congressional leaders to
waive the 60-day review period in hopes of expediting the project.
In a wide-ranging critique of Northwest’s application for a pipeline
right-of-way across federal lands in
Alaska, Behlke told Interior Dept.
officials that the state does not agree that Northwest’s nominal 80-foot
separation between Northwest’s proposed route and the oil
pipeline – which it roughly parallels for about 700 miles within
Alaska – is “automatically acceptable.”
And based on experience with the oil pipeline in
Atigun
Pass, Behlke said, “it is evident
that serious consideration must be given to a tunnel (for the gas pipeline) or
to another alternative route.” In his critique of Northwest’s application,
which he submitted to the Interior Dept. late in July (See All-Alaska Weekly,
Aug. 1, 1989) Behlke cited a long list of complaints centering on Northwest’s
pipeline design and construction plans.
He said he has not had time to review Northwest’s new proposed 200-foot
alignment in detail, but a cursory glance indicates that “a good deal more of
the pipeline would be next to the haul road” than indicated by Northwest’s
alignment.
Behlke has just returned to
Fairbanks from a round of meetings on the
pipeline in and outside of
Alaska. One major topic of discussion, he
said, has been the proposed $3-4 Billion natural gas conditioning plant that
is an integral part of the project. “The state is up to it’s elbows,” he said,
“working very hard to determine whether the economies of locating the plant at
Prudhoe Bay are indeed real economies, or something that came off the wall.”
Northwest’s project plans call for construction of the conditioning
plant at
Prudhoe Bay. But state officials and
Fairbanks boosters want it to be located in
the Interior where gas liquids removed from the raw gas stream during the
conditioning process could be used to promote in-state petrochemical
development.
Behlke said he met with
Northwest officials at their headquarters in
Salt Lake City and urged them to review the
economies of locating the plant at Prudhoe. Northwest’s cost estimates
currently indicate that costs would be greater if the plant were located in
the Interior.
“We asked them to substantiate their figures,” Behlke said, “and to
make sure that the plant is designed properly so that the gas liquids don’t go
down the drain.”
According to Behlke, this month will be a key period for pipeline
planning because many critical issues, such as the site of the conditioning
plant and the rights-of-way alignment are expected to be resolved. “It will be
a hectic, but interesting month for the future of the
pipeline,” he said.
March
6, 1981 ,
The All-Alaska Weekly
Conditioning plant site on
North Slope
confirmed
By JOE LaROCCA
By March of 1981,
two critical decisions contrary to the state's
perceived interests had been reached in the development of plans to
construct a $4 - $6 billion gas conditioning plant to prepare
North Slope
natural
gas for shipment through Northwest Alaskan Pipeline Co.'s proposed Alcan as
pipeline. Both decisions negated the state's contention that the
conditioning plant could be located in the Interior rather than on
Alaska's
North Slope.
Northwest Alaskan Pipeline Company's Design and
Engineering (D&E) Board for the project had decided on a plant design
which used a patented process known as "Selexol" to separate the gas
liquids from the natural gas stream. For technical reasons, this process could
only be utilized if the plant were located on the
North Slope.
At the same time, the Alaska Department of Natural Resources
had conceptually agreed to grant Northwest a lease permit for a 2,000-acre
site for the conditioning plant at
Prudhoe Bay,
although the state and Northwest were still embroiled in a heated dispute over
the terms and conditions of the grant which, Northwest said, could seriously
delay the project.
Both decisions implied the
Hammond
administration's belated
admission that the two-year controversy over the location of the gas
conditioning plant had finally been resolved in favor of Northwest's stated
preference for the
Prudhoe Bay
site, which most Alaskans opposed.
Northwest's selection of a
North Slope
location for the conditioning
plant had been heavily criticized by local government officials in
Fairbanks
and
elsewhere who wanted the facility located in the Interior in order to give the
economy there a much needed boost.
Apart from the stimulus which the construction and operation
of the $4 to $6 billion facility would have provided there, it was also seen
as a prerequisite to the development of an in-state petrochemical industry
based on feedstocks produced from the natural gas liquids, which in turn would
be extracted from the raw gas stream by the conditioning plant.
Among other things, it was expected that a conditioning plant
located in the Interior would have made the gas liquids available for
value-added processing there, and help to launch a multi-million dollar
petrochemical industry within the state.
Critics blamed Northwest's decision to build the conditioning
plant at Prudhoe Bay on the Hammond administration's and the legislature's
joint failure early on to insist on a pipeline design which would have made it
possible to transport the gas liquids to a gas conditioning plant located in
the Interior, near Fairbanks.
While the state has argued that the decision could still be
reversed in the face of other long-standing indications to the contrary, these
two developments - the D&E Board's selection of the "Selexol" process, and the
state's conceptual agreement to grant Northwest a conditioning plant site at
Prudhoe
Bay
- clearly indicated that the decision was irreversible.
The D&E Board was established last June under an agreement
setting forth a preliminary financing plan for the pipeline project which was
signed by Northwest, the
North Slope
oil and gas producers, and the state.
One of the D&E Board's first tasks was to come up with designs for the
pipeline project and the conditioning plant upon which a reliable project cost
estimate could be based, so that the sponsors could proceed with arrangements
to finance the project.
Rough cost estimates of just the Alcan pipeline ranged from
$25 billion to $40 billion, with half that dedicated to the
Alaska segment. It wasn't known whether the D&E Board
has refined the
estimates for the project yet. While the D&E Board's decision in favor
of the Selexol process meant that the gas conditioning plant would be
located on the
North
Slope,
it did not necessarily imply that the gas
liquids would not be available for in-state petrochemical development.
The conditioning plant design could be modified in a way that
would permit the extraction of the gas liquids, if feasibility studies then
underway indicated that a separate small diameter gas liquids pipeline to
ship them to downstream processing facilities would be
economical. However, most experts considered that doubtful.
The Dow-Shell Group, was a consortium of nine
Alaska,
U. S.
and Japanese companies led by Dow Chemical U.S.A. and
the Shell Chemical Co. They undertook comprehensive studies in late
1980 at the
Hammond
administration's behest to ascertain whether
in-state petrochemical production based on
North Slope
gas liquids by
that consortium would be feasible. If so, they would be given an option
by the state to purchase the state's one-eighth royalty share of gas liquids
from
North Slope
natural gas production.
The Group, chosen by the state from amongst several
competitors, had budgeted $5 million for the studies in 1981, and
expected to complete them and submit recommendations to the state by
September.
The Dow-Shell group
indicated earlier that it doesn't matter
whether the D&E Board picked the Selexol process or an alternative
known as the "Salfinol" process, insofar as extraction of the gas liquids
was concerned, because they had assumed from the outset that the gas
conditioning plant would be located on the
North Slope.
If their studies indicated that in-state petrochemical production
based on gas liquids was feasible, the Dow-Shell Group and some of its
members expected to proceed with the design and construction of selected
transportation, production and export-marketing facilities. The state had
agreed to make its one-eighth royalty share - about 25,000 barrels per day -
of
North Slope
gas liquids available for in-state petrochemical processing.
However, several experts have said that most of the remaining
seven-eighths share of the gas liquids owned by the
North Slope
producers would be required to justify the expense of building a separate
liquids pipeline needed to transport them to downstream processing facilities.
While negotiations had been underway between the state, the
North Slope oil and gas producers, and the Dow-Shell group for some time, the
producers had not yet indicated whether they would commit their share of the
gas liquids to any of the prospective facilities being contemplated by the
Dow-Shell Group. On the contrary, they had unequivocally indicated that they
tentatively planned to use the liquids on the North Slope as field and
conditioning plant fuels.
Lt. Gov. Terry Miller, the state's representative on both the
D&E Board and the Dow-Shell Group, said Wednesday that he was very encouraged
by the efforts of both. While the question of economic feasibility had not
yet been answered, Miller told me that "I personally am becoming increasingly
optimistic that the results of the studies will show that an in-state
petrochemical industry based on natural gas liquids will be feasible."
Miller
said he was now convinced that "there's an industry there
that a couple years ago everybody was dismissing."
While the question of the location of the gas conditioning plant
had finally been officially laid to rest, a new controversy quietly erupted
between the state and Northwest Chief Executive John McMillian over a
site for the plant on state lands at
Prudhoe Bay.
In late January, 1981, State Natural Resources Commissioner
Bob LeResche asked Northwest not to submit its application for a separate
lease on a 2000-acre site at Prudhoe Bay under the state's general land
leasing law. LeResche wanted Northwest instead to include its application for
the plant site in its application for the gas pipeline right-of-way over state
lands, in keeping with the state's contention that the conditioning plant is
an integral part of the pipeline project.
But Northwest contended that the conditioning plant was a
separate entity, and the Federal Energy Regulatory Commission (FERC) agreed.
FERC, the licensing authority for energy projects in the
U.S.,
had issued Northwest a conditional certificate for building the pipeline
which, in effect, separated the conditioning plant from the rest of the
pipeline project.
But the state contended that separating the plant from the
pipeline project would have significant adverse impact, and hoped to
persuade FERC to change its position when it issued Northwest a final
certificate.
For
that reason, the state was continuing to insist that Northwest
combine its lease application for the plant site with its application for the
pipeline right-of-way over state lands.
LeResche had also asked Northwest to apply for a temporary
lease or land use permit so that the company could proceed on site work
planned for this summer.
In a strongly-worded telegram on Feb. 13 to LeResche,
McMillian said that Northwest "can find no legal basis for your insistence
that we proceed under (the pipeline right-of-way) rather than (under general
land leasing law). "Neither can we find any legal basis," McMillian added,
"for your plan to convert a temporary use permit into a long-term lease. You
have not responded," the Northwest executive told LeResche, "to our request
for a statement of legal authority to support your position."
Said McMillian: "The inevitable consequences of this refusal to
permit us to proceed immediately under (general leasing law) as we are
prepared to do would delay the issuance of a long-term lease for the
conditioning plant site until pipeline right of way negotiations are
completed."
He added: "The gas conditioning facility is the pacing item for
the over-all project. If you persist in your present position, you must be
prepared to accept the responsibility for a project delay, with the resulting
increased costs to
U.S.
consumers who utilize Alaskan gas and the postponement of the use of Alaskan
gas as a substitute for imported OPEC oil."
McMillian told
LeResche that "We are effectively blocked by state
inaction from proceeding further," and "cannot hold the project schedule if
you hold your present course of conduct."
LeResche was traveling out of the state when McMillian
dispatched his telegram, so it was forwarded to Governor Jay Hammond. In response, the
Governor told McMillian that all permits and authorizations for land use
within the
Prudhoe Bay
unit must be coordinated with the unit operators (ARCO and BP).
Hammond
said the operators had been notified of Northwest's application for a
lease for the conditioning plant site,
and the state was awaiting their reply. Said
Hammond:
"The
Commissioner's temporary absence is in no way delaying actions by the
state. He told McMillian that the state attorney general had advised him
there was sufficient legal basis to issue a temporary lease or special land
use permit which would allow site preparation to proceed as scheduled for the
1981 season.
The Governor also told McMillian that there appeared to be
some confusion over who should be issued the lease or permit. "Our
representatives to the D&E Board do not recall Northwest being authorized by
the board to seek this lease,"
Hammond
said. And he asked McMillian to send the state "the relevant portions of the
minutes containing such authorization."
Mary Halloran, a special assistant to LeResche, said time was
growing short for Northwest to apply for the permits it needed to proceed with
work on the conditioning plant site during the short summer construction
season on the
North Slope.
Northwest planned to purchase gravel from the state for the plant's
foundation, and competitive gravel disposal procedures, including public
notice and comment, must he followed which would take at least 60 days to
complete.
Said Halloran: "It's perfectly clear, regardless of what we do
with the long-term lease, that there are procedures for doing what they want
to do this summer. But we have to receive their applications soon," Halloran
told me. "This is a bureaucracy, and we have to have the paperwork."
From the All-Alaska Weekly,
October 8, 1982
CO2 Content is Key to Economic
Viability Of
All-Alaska Gas Pipeline
By JOE LaROCCA
Can the lower costs of conditioning
North Slope natural gas at a pipeline terminus on
Alaska’s south coast outweigh the loss of
pipeline capacity devoted to the unavoidable shipment of a sizeable but
worthless component of the raw gas – carbon dioxide? That’s a critical
economic question facing proponents of an All-Alaska pipeline which would
carry natural gas and gas liquids from
Prudhoe Bay to a southern
Alaska seaport.
It’s one of many questions currently under study by a citizen’s
advisory committee appointed last summer by Gov. Jay Hammond to
consider alternatives for getting
North Slope natural gas to market.
The committee, co-chaired by two former governors – Bill Egan
and Wally Hickel – has retained Brown and Root of Houston to undertake
engineering and economic feasibility studies. The committee is to submit its
report to the legislature when it convenes in January.
Don Hale, manager of Root’s pipeline engineering department,
was in
Anchorage this week in connection with the
study. He will submit a progress report to the committee, which is scheduled
to meet there today.
Hale, a veteran of pipeline engineering in
Alaska, first worked here in 1958. He
emphasized that the proposed all-Alaska pipeline is a concept, not a final
design. “Not a bit of this is set in concrete,” he said. “We’re not
proclaiming that it’s a designed system, but it’s pretty well thought-out.”
Under the proposal, the entire natural gas and gas liquids stream would
be separated from the crude oil stream at
Prudhoe Bay, refrigerated and pumped directly into the
proposed gas line. On the other hand, under the Natural Gas Transportation
System (ANGTS) designed by Northwest Alaskan Pipeline which would be routed
partly through
Canada, the raw gas would be
stripped of water, natural gas liquids (NGLs) and carbon dioxide, cleaned and
conditioned at
Prudhoe
Bay before entering Northwest’s
proposed pipeline.
The carbon dioxide would be discharged into the atmosphere and most of
the NGLs would be used as field fuels on the
North Slope. That processing would require the
construction of a gas conditioning plant there, estimated to cost $6 billion.
But Hale says the the exorbitant costs of building, operating and
maintaining a gas conditioning plant on the North Slope can be avoided by
simply transporting all the raw gas and gas liquids
through the proposed all-Alaska gasline for processing at
points south, where industrial costs would be much lower.
“Anything done on the
North Slope is more costly than farther south,” he
said. “We can get away from processing there by bringing the total gas stream
down to a tidewater location, then do the processing where it’s more
controllable and economic.” Instead of putting processing and extraction
facilities at
Prudhoe Bay,” Hale said, “we would transplant
Prudhoe Bay to tidewater.”
But relocating the gas conditioning facilities at the pipeline’s
southern terminus mans that significant chunk of its
capacity would be taken up by non-productive carbon dioxide, which constitutes
about 12 percent of the raw gas stream. The central question is whether the
greater cost of building and maintaining the gas conditioning facilities on
the
North Slope would outweigh the cost imposed by shipping
the un-usable carbon dioxide through the length of the pipeline. Hale said the
economies realized by avoiding the higher
North Slope costs “may have a positive effect that’s
greater than the negative effect of carrying the carbon dioxide.”
While the CO2 content is presently considered a liability, it’s
possible that some of it can be profitably utilized : for example, in tertiary
– or third-stage - recovery of crude oil from depleting
pools in
Cook Inlet; or, in the long term, to produce urea
there, of which there is currently a world glut, Hale said.
The Brown and Root study contemplates a 36-inch diameter, high-pressure
pipeline and 14 compressor stations with a maximum design capacity of 2.8
billion cubic feet per day. To accommodate the higher pressure, the pipe wall
would be made of thicker and tougher steel than Northwest Pipeline’s proposed
48-inch diameter line, although total steel tonnage would
be nearly the same, according to Hale. But because of the higher pressure, he
said, “we can carry the same volume in a 36-inch line as they can in a
48-inch.
“The (all-Alaska) project will benefit by utilization of al the heavier
hydrocarbons (NGLs),” Halke said. “hauling those heavier ends would overcome
the deficit effect of hauling the CO2,” he said. But he
declined to specify the level of pressure under consideration.
Northwest has set 1260 pounds per square inch (psi) as the pressure for
the
Alaska segment of its proposed pipeline.
That’s well above the pre-existing industry standard for large diameter gas
pipelines, although some interested parties unsuccessfully argued for a higher
pressure line which would accommodate more of the NGLs.
The state of
Alaska, for example, pressed for a level of
1470 psi for the Alask segment of the Northwest pipeline. And Exxon contended
that 2000 psi, while unprecedented, would be feasible. (The controversial
pipeline pressure issue was eventually decided in Northwest’s favor by a
federal circuit court of appeals in Jan., 1980 on purely legal, not technical
grounds).
Hale said the all Alaska pipeline concept assumes that all of the gas
and gas liquids from Prudhoe Bay – the producers’ seven-eighths share, and the
state’s one-eighth royalty share – would be available for shipment down the
line. That assumption, among others, has already come under attack by some
critics who say the producers are not likely to commit their shares to such a
transportation system.
Hale said the committee’s study does not encompass end uses of the gas
stream, but stops with the delivery of the gas to tidewater. Other interested
parties would deal with the other commercial and industrial aspects, which
could include shipping liquefied natural gas LNG) and gas liquids via ocean
tankers to
U.S.,
Pacific Rim, and other markets; or petrochemical
production within
Alaska.
Hale said the committee’s report to the legislature would include
findings on the economic and technical feasibility of the various
alternatives; cost estimates bearing a “high degree of confidence;” and
whether further in-depth evaluation and study of one or more alternatives is
warranted. The committee has publicly stated that one possible outcome is that
the studies may indicate none of the options is viable.
Other options the committee is considering include continued state
support for the Northwest pipeline project; construction of a smaller gas
pipeline to
Fairbanks; generating electrical power
within
Alaska, and petrochemical manufacturing.
Several other organizations are working for or with the committee. They
include a Dow-Shell joint venture; the Mitsubishi Research Institute;
Dillon, Reed and Co., the New York investment firm which is looking at
the financial aspects of the various options, and Birch,
Horton, Bitner and Monroe with offices in Alaska and Washington, D.C., which
has been retained to provide legal services.
From the All-Alaska Weekly,
October 29, 1982
Gas Pipeline an Example of
U.S. Energy
Policy ‘Gone Haywire,' says
Congressman
By JOE LaROCCA
The stalled
Alaska Highway gas pipeline is “an example of our
natural gas policy gone haywire,” a ranking Republican congressman from
Illinois told an industry group in
Chicago recently. And legislation passed by
Congress last year which enables the sponsors of the pipeline to “pre-bill”
consumers for gas they may never get or need” should be repealed by the end of
next year if the project hasn’t gotten underway, he added..
Rep. Tom Corcoran, addressing a meeting of the Chemical
Manufacturers Assn. earlier this month said he introduced a joint resolution
last April which would put a two-year time limit on the effect of the
controversial waivers adopted by Congress in December of 1981.
The pipeline sponsors and their supporters said that private sector
financing of the project, which is required by federal law, could not be
secured without passage of the waivers. The most controversial waiver is one
which enables the owners of the proposed pipeline to bill gas consumers for
certain project costs even if it’s never completed.
Several months after Congress approved the waivers, the sponsors,
Northwest Alaskan Pipeline Co., put the project on the shelf for at least two
years because they were unable to arrange private sector financing even with
the waivers.
One “unfortunate aspect of this,” Corcoran said, “is that waivers last
forever – there is no expiration date involved with those
waivers.” He said his resolution, HJR 467 “would place
just such a cap on the effectiveness of those waivers as well as re-state that
there would be no federal financial assistance forthcoming on this project.”
According to Rep. Corcoran, who unsuccessfully fought approval of the
waivers, 40 House members have joined as co-sponsors of the measure, including
several who voted in favor of the waivers last December.”
If passed by Congress, the resolution would have the force of law and,
in effect, repeal the waivers by
Dec. 15, 1983, if
financing has not been arranged and work resumed on the project by then.
Said Corcoran: “I am certainly not opposed to making use
of natural resources we have in Alaskan natural gas. However, I do strongly
object to the method by which the consortium proposes to
“pre-bill” certain natural gas ratepayers for gas they may never get or need.”
In his Oct. 4 speech, the Illinois Republican strongly criticized
several other aspects of the
U.S. government’s natural gas
policy which call for importing “the most exotic, most expensive and least
desirable supplies of gas.” These include the importation of liquefied natural
gas (LNG) from
Algeria, and surplus natural gas
from
Canada, at a time when vast
supplies of lower-priced domestic gas are available.
“It seems incredible that Panhandle (Eastern Pipeline Co,) would choose
a time like this now to commence imports of Algerian LNG…Virtually every
natural gas pipeline in the country now has more natural gas than it can sell
and is shutting in significant amounts of domestic natural gas production. In
fact,” he said, “in
Ohio, there is so much natural gas that it
is actually being flared (burned off) during production.
Corcoran, a member of the House Energy and Commerce Committee and two
other energy-related subcommittees said: “I am not opposed to the importation
of Canadian gas, per se. But I do object to such importation at a more
expensive price than domestic Lower 48 gas, and at a time when we have in our
country large quantities of our own gas.”
Corcoran said he’s not “overly critical” of Panhandle’s judgment to
pursue the Algerian option back in the mid-70s.”At that time the conventional
wisdom was that there was a shortage of natural gas. But
“Times have changed, and maybe we ought to look closely at the federal energy
laws that came out of that era,” he said.,
While blaming the Democratic majority in the House of Representatives
and the Carter administration for “natural gas policy gone haywire,” Corcoran
admitted that “Republicans are not without fault.” For instance, he said, “it
was a Republican president (Reagan) who submitted to Congress the pipeline
waiver package, which was “dictated by Senate Republicans” and supported by “a
good many Republicans.”
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