pipelines & downstream conditional approvalsee hilcorp-bp sale page 12 see oil prices page 10 see...
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l F I N A N C E & E C O N O M Y
l P I P E L I N E S & D O W N S T R E A M
page 8
Vol. 25, No. 51 • www.PetroleumNews.com A weekly oil & gas newspaper based in Anchorage, Alaska Week of December 20, 2020 • $2.50
see ARCTIC FINANCING page 9
l E X P L O R A T I O N & P R O D U C T I O N
ANS production, prices, down this year; volumes to rise long term
The Alaska Department of Revenue
released its Revenue Sources Book Dec.
11, with projections reflecting a decrease
in Alaska North Slope crude oil prices
and decreasing production.
“Drilling and investment were sharply
reduced this year, and are reflected in the
lower near-term forecast, but we are
hopeful that new developments will con-
tribute to stabilizing production over the
coming decade,” Revenue Commissioner
Lucinda Mahoney said in a cover letter.
see CARBON TAX page 10
Suits ask injunctions to block Coastal Plain lease sale, seismic
Two suits were filed Dec. 15 against plans by the U.S.
Department of the Interior to offer oil and gas leases on the
Coastal Plain of the Arctic National Wildlife Refuge on Jan. 6.
The suits also contest winter seismic exploration on the
Coastal Plain, for which Interior’s Bureau of Land
Management released an environmental assessment Dec. 16
(see story in this issue).
The suits filed in U.S. District Court for the District of
Alaska ask for a temporary restraining order and preliminary
injunction against Secretary of the Interior David Bernhardt
and the North Slope Borough (case in which the Gwich’in
Steering Committee is the lead plaintiff) and for a preliminary
injunction against Bernhardt and the Alaska Oil and Gas
see ANWR INJUNCTIONS page 11
see REVENUE FORECAST page 10
State of Alaska approves Jade Energy’s Point Thomson Area F POD
Trudeau rolls out carbon tax of C$170 per metric ton by 2030
Canadian Prime Minister Justin
Trudeau has ended five years of promis-
es, pledges and commitments, all lost in
a mountain of stalling, by rolling out a
climate change policy that will see the
carbon tax soar from C$15 per metric ton
today to C$170 by 2030.
The goal is to reduce greenhouse gas
emissions to 30% below 2005 levels by
2030, a target the Trudeau government is
lagging far behind.
“This plan for a healthy environment and a healthy econo-
my was developed for the federal government,” Trudeau said,
Conditional approval RCA rules on Harvest Alaska acquisition of BP Pipelines (Alaska)
By KRISTEN NELSON Petroleum News
T he Regulatory Commission of Alaska has given conditional approval to the sale of BP’s midstream assets to Harvest Alaska, a process
which began after BP announced in August in
2019 that it was selling its Alaska assets to Hilcorp
(Harvest is Hilcorp’s midstream affiliate). The
companies filed with RCA for transfer of mid-
stream assets in September 2019.
Transfer of upstream assets in the sale, with the
state’s analysis headed up by the Alaska
Department of Natural Resources, was approved
this September.
In its Dec. 14 order, the company said it
received both public and confidential information.
Usually, it said, its evaluation of applications “is
usually based on publicly disclosed information.”
“The fact that we must base the decisions on
these applications in large part on confidential
information has complicated and lengthened our
review and slowed preparation of this order.
Oil makes steady price Various factors drive ANS, Brent above $50 for week; federal stimulus promised
By STEVE SUTHERLIN Petroleum News
O il prices are teasing at a new trading range above $50 per barrel. Alaska North Slope crude closed at $51.25 on
Dec. 15, up 84 cents on the day and above Brent
crude, which closed at $50.73, down 44 cents.
West Texas Intermediate closed at $47.62, a
gain of 63 cents on the day.
Brent traded at $51.13 and ANS at $51.61 at
Petroleum News press time Dec. 16, while WTI
traded at $47.82.
ANS and Brent have closed above $50 each day
beginning Dec. 10.
An air of optimism surrounded oil trading desks
as economic stimulus talks in the U.S. Congress
appeared to gaining support across party lines.
On Dec. 16, Congress was said to be near a deal
on a stimulus package nearing $900 billion,
including the surprise addition of a new round of
stimulus checks, albeit smaller than the last pay-
ments of $1,200 — part of the stimulus package
passed in March.
U.S. Treasury Secretary Jay Powell, in a post-
Federal Open Market Committee press conference
Conveyor belt of prospects Oil Search exec: Alaska North Slope ideal place for climate change transition
By KAY CASHMAN Petroleum News
Earlier this month Oil Search Alaska COO Matt Elmer said Alaska offers his company a “con-veyor belt of opportunities” from west to east across
the North Slope. The third largest
leaseholder in the state, Oil Search
drilled four new wells in the two
and a half years since it became a
North Slope operator, increasing its
contingent oil reserves from approximately 500 mil-
lion to 1 billion barrels.
“Pikka’s just the start. We have a number of
opportunities to develop after Pikka” from the west-
ern to the eastern North Slope, Elmer said in his
early December presentation to a virtual meeting of
the Resource Development Council in Anchorage.
He also said Alaska’s North Slope is “the ideal
place to be developing and managing the climate
change transition” for oil and gas companies. “It’s a
mature basin. It has existing and underutilized infra-
structure” such as a pipeline system across the Slope
that connects to the 800-mile trans-Alaska pipeline
which transports oil to the port of Valdez.
This is a story he hopes Alaskans will “get out
there” and tell naysayers, “especially in the
finance world where Arctic developments are get-
ting a bad rap.”
The “good thing” about a new field in northern
see HILCORP-BP SALE page 12
see OIL PRICES page 10
see ANS OPPORTUNITIES page 11
No, thanks! to red-lining banks: governor slams anti-Arctic bias
Alaska Gov. Mike Dunleavy said his
administration will introduce legislation
requiring state departments and agencies
to end existing relationships and partner-
ships with financial institutions that have
chosen to stop financing oil and gas
exploration and development in the
Arctic.
“We are the only arctic state in the
nation. For over 40 years, the United
States has benefited greatly from explo-
ration and development of our arctic resources,” Dunleavy
said in a Dec. 14 statement. “It makes no sense for Alaska to
GOV. MIKE DUNLEAVY
LUCINDA MAHONEY
JUSTIN TRUDEAU
“BPPA has retained the obligation to pay for most of what would otherwise
become, after closing of the Midstream Transaction, Harvest Alaska’s share of
TAPS DR&R,” RCA said.
OPEC crude oil production in November increased by 0.71 million bpd, month over
month, to average 25.11 million bpd, according to secondary sources.
http://www.petroleumnews.com
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2 PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020
Petroleum News Alaska’s source for oil and gas newscontents
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Dependadoug.Sourt www
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l E X P L O R A T I O N & P R O D U C T I O N
US drilling rig count jumps 15 to 338 By KRISTEN NELSON
Petroleum News
T he Baker Hughes U.S. rotary drilling rig count had its largest weekly increase this year, up by 15 for the week ending Dec. 11 to 338, but still down by 461
from a count of 799 a year ago.
When the count hit 244 the week of Aug. 14, it was
not just the low for 2020, but the lowest it has been since
the Houston based oilfield services company began issu-
ing a weekly U.S. rig count in 1944.
Prior to this year, the low was 404 rigs in May 2016.
The count peaked at 4,530 in 1981.
At the beginning of the year the count was in the low
790s, where it remained through mid-March, when it
began to fall, dropping below what had been the historic
low in early May with a count of 374 and continuing to
drop through the third week of August when it gained
back 10 rigs.
The Dec. 11 count includes 258 rigs targeting oil, up
12 from the previous week but down 409 from 667 a
year ago, 79 rigs targeting gas, up by four from the pre-
vious week but down 50 from 129 a year ago, and one
miscellaneous rig, down by one from the previous week
and down two from a year ago.
Seventeen of the holes were directional, 306 were
horizontal and 15 were vertical.
Alaska count unchanged Texas, with the most active rigs at 155, was up six
from the previous week, although still down 245 from
400 a year ago.
Wyoming (5) was up by four rigs from the previous
week; Pennsylvania (19) was up by two rigs.
New Mexico (60), Ohio (5) and Oklahoma (14) were
each up by a single rig from the previous week.
Rig counts were unchanged in the remaining states:
Alaska (3), California (6), Colorado (7), Louisiana (40),
North Dakota (11), Utah (3) and West Virginia (9).
Baker Hughes shows Alaska with three active rigs
Dec. 11, unchanged from the previous week but down by
three from a year ago.
The rig count in the Permian, the most active basin in
the country, was up by four from the previous week at
168, but down 232 from a count of 400 a year ago.
International count up Baker Hughes released its international count for
November on Dec. 4.
The international count averaged 669, up by 13 rigs
from the October average, with land rigs up seven to 509
and offshore rigs up six to 160.
The company said the international average rig count
for November is down 427 from 1,096 last year — with
land rigs down 340 and offshore rigs down 87.
The U.S. rig count averaged 310 in November, up 30
from the October average and down 500 year-over-year.
The average Canada rig count was 95 in November,
up from 80 in October and down 41 year-over-year.
The worldwide count for November (international
and North America combined) averaged 1,074, up 58
from October and down 968 from 2,042 in November
2019. l
Conditional approval RCA rules on Harvest Alaska acquisition of BP Pipelines (Alaska)
Oil makes steady price Various factors drive ANS, Brent above $50 for week
Conveyor belt of prospects Oil Search: Alaska North Slope ideal for climate change transition
ON THE COVER
No, thanks! to red-lining banks: governor slams anti-Arctic bias
ANS production, prices, down this year; volumes to rise long termTrudeau rolls out carbon tax of C$170 per metric ton by 2030Suits ask injunctions to block Coastal Plain lease sale, seismic
ENVIRONMENT & SAFETY6 Hilcorp has Trading Bay slop oil release
2 US drilling rig count jumps 15 to 338EXPLORATION & PRODUCTION
6 RCA continues drafting ERO regulations Ensuring balance in governance over management of Railbelt electrical system requires careful wording of certification rules
3 Whitecap rides waves of change Moves into ranks of Canada’s top 10 publicly traded oil and gas companies with takeover of Torc Oil & Gas
UTILITIES8 Congress approves more US icebreakers
7 KIC seismic environmental assessment out8 State of Alaska approves Jade 3rd POD
GOVERNMENT
FINANCE & ECONOMY
3 State approves PA expansion at Kuparuk Expansion at Kuparuk River unit is 13th for participating area, currently 194,428 acres, will grow by 3,360 to 197,788 acres
4 ConocoPhillips gets OK on Colville projects State of Alaska OKs CRU unit amendments to install temporary camp on Kuukpik pad, erect drilling support office on CD1 pad
http://www.sourdoughexpress.com
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By GARY PARK For Petroleum News
Whitecap Resources is pullingz out the stops to bolster its position in the ranks of Canada’s mid-sized oil and
natural gas producers, opting for
takeovers rather than organic growth.
In its biggest strike yet, Whitecap is
buying Torc Oil & Gas in a C$565 mil-
lion all-stock deal, while assuming debt
estimated at C$335 million.
Once the transaction closes early in
2021, Whitecap estimates it will pump
out 100,000 barrels of mostly light-grade
oil equivalent per day
The deal comes four months after the
company announced it was acquiring pri-
vately held NAL Resources for C$155
million to gain output of 27,000 boe per
day.
“We believe this is a good time for
consolidation,” said Whitecap Chief
Executive Officer Grant Fagerheim.
“We believe sale and size does mat-
ter,” he said. “If you are not advancing or
growing you are regressing.”
Completion of the takeover will make
Whitecap the ninth largest publicly traded
oil and gas company in Canada, with an
enterprise value of about C$4 billion.
Cody Kwong of Stifel FirstEnergy
said that by rounding up Torc and NAL,
Whitecap will gain more attention from
investors by positioning itself as a “con-
solidator of choice.”
“You’re in an M&A market that favors
a buyer. It’s a lot more efficient to add
barrels through acquisition than it is to do
it on an organic basis by drilling,” he said.
“If the M&A market is hot for you,
you don’t want to just nibble at the edges
if there’s an opportunity. You want to
make a big sting when you can.”
Jeremy McCrea, an analyst at
Raymond James, said that as many com-
panies seek buyers because of their heavy
debt loads and constrained investment
capital, the market is rewarding mergers
that bring together well-run companies in
no need of rescue.
In order to attract more attention “so
that you can get access to outside equity”
companies must pursue size, he suggested.
Companies good fit Whitecap and Torc present an ideal fit,
with Torc’s oil operations in southeastern
Saskatchewan and west-central Alberta
having a 92% overlap with Whitecap.
Torc’s major shareholder with a 29%
stake is the Canadian Pension Plan
Investment Board, which manages C$456
billion in contributions from workers and
employers.
The buying opportunities have grown
with word from Imperial Oil (69.6%
owned by ExxonMobil) that it is writing
down up to C$1.2 billion of mostly oil
sands assets it never expects to develop,
while it concentrates on natural gas
prospects that are rich in petroleum liq-
uids.
That moves comes after France’s Total
said earlier this year it was taking a US$8
billion impairment on the value of its
mainly Canadian oil sands holdings.
Canadian Natural Resources, which
acquired debt-laden Painted Pony Energy
for C$461 million earlier this year, said it
plans to hike its capital budget to C$3.2
billion in 2021 (up C$500 million from
2020), and boost output by 5% or 62,000
boe per day to 1.23 million boe per day.
Canadian Natural Resources President
Tim McKay said that “as COVID-19
works through the system we will see
what the demand does to pricing. If we
see shipping opportunities (Enbridge’s
Line 3 and the Trans Mountain expansion
in 2022) come to fruition in terms of
egress (to the U.S. and Asia) and pricing
we are nimble enough to adjust.”
With its inventory of longer-life assets
Canadian Natural said it has near- and
mid-term growth potential to add
245,000-285,000 boe per day.
Production in Alberta is forecast to dip
by 250,000 bpd this year, reflecting shut-
ins following the spring price collapse,
but is expected to rebound by 7% in 2021
to 3.5 million bpd. l
PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020 3
®Providing integrated environmental and engineering solutions for the oil and gas industryRick Farrand (907) 343-2705
l E X P L O R A T I O N & P R O D U C T I O N
State approves PA expansion at Kuparuk Expansion at Kuparuk River unit is 13th for participating area, currently 194,428 acres, will grow by 3,360 to 197,788 acres
By KRISTEN NELSON Petroleum News
T he Alaska Department of Natural Resources’ Division of Oil and Gas has approved the 13th expansion of the Kuparuk participating area at the Kuparuk River unit on the
North Slope.
ConocoPhillips Alaska, the Kuparuk unit operator,
applied for the expansion in June. Prior to that the Kuparuk
PA was 194,428 acres. With the 3,360-acre addition, there
are now 197,788 acres in the PA.
The Kuparuk PA is the largest at the Kuparuk River unit.
Others are Meltwater, Tabasco, Tarn, West Sak and NEWS.
In its application the company said confidential informa-
tion included showed the 13th expansion area “is reasonably
estimated to be capable of producing or contributing to the
production of oil in paying quantities.”
The division agreed, approving the expansion Dec. 14.
The decision, signed by Director Tom Stokes, included a
brief history of the Kuparuk River oil pool, which was dis-
covered at the Sinclair Ugnu No. 1 well in 1969.
“In terms of area, this pool is the second largest on the
Arctic Slope of Alaska, occupying approximately 500
square miles,” and is defined as the accumulation of oil com-
mon to and correlated with the accumulation found in the
ARCO West Sak River State No. 1 between measured
depths of 6,474 and 6,800 feet, the division said.
Production from the Kuparuk PA began in December
1981 and peaked in 1992 at an average of 324,000 barrels
per day. In 2019, daily production from the KPA averaged
73,000 bpd, with cumulative production from the KPA of
more than 2.5 billion barrels of oil.
The KPA has been expanded 12 times “as drilling and
advancing technology has continued to expand the produc-
tive margins of the field,” the division said.
The acreage proposed for the 13th expansion is in two
areas along the western periphery within the unit — the
northern area, some 2,880 acres, between existing Kuparuk
drill sites 3G and 3S (Palm) and the southern area, some 480
acres, west of drill sites 2A and 2T.
Recent development The division said ConocoPhillips Alaska has, in addition
to infill drilling, “expended resources acquiring new and re-
interpreting existing seismic data to better delineate and
expand development along the periphery of the existing
developed Kuparuk reservoir.” This activity, along with
advances in drilling technologies, “have enabled CPAI to
detect and develop thinner net pay intervals found along the
margins of the reservoir.”
The 3S-08 well, drilled in 2003 between the 3S and 3G
drill sites, confirmed sands in both Kuparuk A and C inter-
vals, “but was sidetracked to another location prior to com-
pletion.”
The company drilled and completed the 3G-28, a produc-
er, and the 3G-27, an injector — both horizontal wells,
“directly south of the original 3G-08 well in State Lease
ADL 25546,” the division said. The initial peak oil rate from
3G-28 exceeded 2,700 bpd in September 2019; currently the
well is producing some 700 bpd.
“Since 3G-27 and 3G-28 are currently outside the exist-
ing KPA, they are both operated as Unit Tract Operations
until the KPA is expanded to include them.” Results of the
wells “demonstrate that a productive reservoir is present,
l F I N A N C E & E C O N O M Y
Whitecap rides waves of change Moves into ranks of Canada’s top 10 publicly traded oil and gas companies with takeover of Torc Oil & Gas in C$900 million deal
see PA EXPANSION page 4
http://www.lounsburyinc.comhttp://www.westonsolutions.com
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4 PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020
ADDRESS P.O. Box 231647 Anchorage, AK 99523-1647 NEWS 907.522.9469 [email protected] CIRCULATION 907.522.9469 [email protected] ADVERTISING Susan Crane • 907.770.5592 [email protected]
OWNER: Petroleum Newspapers of Alaska LLC (PNA) Petroleum News (ISSN 1544-3612) • Vol. 25, No. 51 • Week of December 20, 2020
Published weekly. Address: 5441 Old Seward, #3, Anchorage, AK 99518 (Please mail ALL correspondence to:
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Petroleum News and its supplement, Petroleum Directory, are owned by Petroleum Newspapers of Alaska LLC. The newspaper is published weekly. Several of the individuals
listed above work for independent companies that contract services to Petroleum Newspapers of Alaska
LLC or are freelance writers.
Kay Cashman PUBLISHER & FOUNDER
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Kristen Nelson EDITOR-IN-CHIEF
Susan Crane ADVERTISING DIRECTOR
Heather Yates BOOKKEEPER
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Renee Garbutt CIRCULATION MANAGER
ANWR: No Seismic? No Problem.
Learn about an alternative land valuation strategy using our proprietary modeling system
for undiscovered oil.
Explore a demo scenario in the ANWR 1002 Area here: https://bit.ly/3m0EBok
Contact: Erik Anderson
[email protected] Cell: (781) 307-5448
CORRECTIONW. Harrison Bay application filed in July
In the Sept. 6 and Sept. 13 issues of Petroleum News the filing date for the
West Harrison Bay unit application was given as June 27. On Dec. 10 Alaska’s
Division on Oil and Gas posted an Errata 1 item on its website, correcting the date
in its records from June 27 to July 27.
and in conjunction with updated mapping,
support the interpretation that a sufficient
resource is present to support drilling addi-
tional wells in the future within the proposed
northern expansion area,” the division said.
In the smaller, southern expansion area,
ConocoPhillips used a CTD rig to drill and
complete horizontal production lateral wells
2A-22A and 2A-22AL1 within a portion of
lease ADL 25571 outside the current KPL
boundary. Those two wells currently pro-
duce a combined rate of some 230 bpd. In
2018 the company drilled and completed
two CTD horizontal production lateral well-
bores from the existing Kuparuk 2T-37
wells in lease ADL 25568, one of which, 2T-
37L1-01, “extends, and is producing, from
beyond the current KPA boundary.”
The division said the southern portion of
the proposed expansion encompasses “lands
currently allocated production with an
approved tract operation.”
The division said it found that the 13th
expansion of the KRA promotes conserva-
tion of all natural resources, promotes pre-
vention of economic and physical waste and
provides for the protection of all parties of
interest, including the state. l
continued from page 3
PA EXPANSION
l E X P L O R A T I O N & P R O D U C T I O N
ConocoPhillips gets OK on Colville projects State of Alaska OKs CRU unit amendments to install temporary camp on Kuukpik pad and erect drilling support office on CD1 pad
By KAY CASHMAN Petroleum News
O n Dec. 9 and Dec. 10 Alaska’s Division of Oil and Gas approved Colville River unit plan of opera-tions amendments allowing operator ConocoPhillips to
install a temporary camp on the Kuukpik pad and erect a
permanent drilling support office on Colville Delta No.
1 pad, or CD1 pad. The new infrastructure will support
western North Slope oil and gas operations and activities
with work on both projects beginning soon.
The personnel camp and its supporting infrastructure
will be used for less than 12 months, with all the work per-
formed on the Kuukpik pad, which is in the North Slope
Brough Resource Development District on surface land
owned by Kuukpik Corp. Work will begin on Jan. 15.
The camp and its infrastructure will support activities
at CD1, CD2, CD3, CD4 and CD5 pads and consist of
“multiple modules, including personnel camps, offices,
water modules, waste modules, connector modules, con-
trol modules, smoke shacks, rec/lounge module, facili-
ties, connexes, equipment shops and storage facilities,”
per ConocoPhillips’ Dec. 4 application. Generators and
supporting diesel fuel tanks will also be located within a
generator module in the vicinity of the camp. Both the
generator modules and the waste/water tank modules
will be placed in secondary containment.
Erection of the drilling office on the CD1 pad, which
was applied for on Nov. 20, is scheduled to start imme-
diately and be completed by March
31. It will remain on the pad until
the end of field life.
The office will be placed on a
timber foundation and power con-
nected by trenching to the Remote
Electronic Instrumentation Module,
or REIM, in the nearby Titan Tent.
The trench to install the electri-
cal cables will measure approxi-
mately four feet in width, five feet
in depth, and 150 feet in length. The materials excavated
from the trench will be used as backfill after the electri-
cal cables are installed. Stairs, walkways, mobile bull
rails, and jersey barriers will also be installed as part of
the project.
CD1 is approximately eight miles north of Nuiqsut on
a state of Alaska lease.
Drilling activities planned ConocoPhillips Alaska President Joe Marushack said
Nov. 18 that in the wake of the defeat of Ballot Measure
1 and a stabilization of oil prices in the $40 range, the
company expects to restart drilling projects on the North
Slope beginning in mid-December, pending corporate
budget approvals.
The following activities are planned:
• Start up Doyon Rig 25 before year end 2020 to
resume the drilling that was halted at CD5 in April due
to COVID-19.
• To begin 2021, Doyon 25 will move from CD5 to
drill at GMT2. “We will start drilling there in the first
half of 2021 with first oil planned in the fourth quarter.
GMT2 will require an additional 35 miles of ice roads,
100-acre ice pad, and a 3-acre multi-season ice pad
which will be built starting in January,” Marushack said.
• A 25-day turnaround at Alpine in July 2021 “which
will allow us to execute the Alpine Brownfield expan-
sion projects that include the Slug Catcher, Gas
Expansion and Power Expansion.”
• In the second half of 2021, commission and start-up
the new build extended reach drilling rig, Doyon 26 (also
known as the Beast), which will begin drilling the Fiord
West field from the Alpine CD2 drill site.
• Also, in the second half of 2021, drilling in the
Kuparuk River unit will restart. “We are planning on
bringing a coiled tubing drilling rig back to the field, as
well as a rotary rig workover program.”
Marushack also said Prudhoe Bay unit activity “is
dependent on reaching a consensus with the major work-
ing interest owners. That discussion is still under way.”
More on Fiord West The CD2 pad was extended to 12 acres to accommo-
date the big ERD rig and development.
Other drilling rigs do not have the capability to access
JOE MARUSHACK
see COLVILLE PROJECTS page 6
http://www.nalcochampion.comhttp://www.petroleumnews.com
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PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020 5
Welcome to Alaska Mr. Gardes
Acuren
AES Electric Supply, Inc
Afognak Leasing LLC
Ahtna, Inc.
Airport Equipment Rentals
Alaska Dreams
Alaska Frontier Constructors (AFC)
Alaska Fuel Services
Alaska Marine Lines
Alaska Materials
Alaska Railroad
Alaska Steel Co.
Alaska Tent & Tarp
Alaska Textiles
Alaska West Express
Arctic Controls
ARCTOS Alaska, Division of NORTECH
Armstrong
AT&T
Avalon Development
Bombay Deluxe
BrandSafway Services
Brooks Range Supply
C & R Pipe and Steel
Calista Corp.
ChampionX
Chosen Construction
Colville Inc.
Computing Alternatives
CONAM Construction
CTG
Cruz Construction
Denali Universal Services (DUS)
Doyon Anvil
Doyon Associated
Doyon Drilling
Doyon, Limited
EEIS Consulting Engineers, Inc.
Egli Air Haul
exp Energy Services
F. R. Bell & Associates, Inc.
Flowline Alaska
Frost Engineering Service Co. – NW
Fugro
GCI
GMW Fire Protection
Greer Tank & Welding
Guess & Rudd, PC
HDR Engineering, Inc.
ICE Services, Inc.
Inlet Energy
Inspirations
Judy Patrick Photography
Little Red Services, Inc. (LRS)
LONG Building Technologies
Lounsbury & Associates
Lynden Air Cargo
Lynden Air Freight
Lynden Inc.
Lynden International
Lynden Logistics
Lynden Transport
Maritime Helicopters
Nabors Alaska Drilling
NANA Worley
NEI Fluid Technology
Nordic Calista
North Slope Borough
North Slope Telecom
Northern Air Cargo
NRC Alaska, a US Ecology Co.
Oil Search
PND Engineers, Inc.
PRA (Petrotechnical Resources of Alaska)
Price Gregory International
Raven Alaska – Jon Adler
Resource Development Council
SeaTac Marine Services
Security Aviation
Shoreside Petroleum
Soloy Helicopters
Sourdough Express
Strategic Action Associates
Tanks-A-Lot
Weston Solutions
Wolfpack Land Co.
Alaskans welcome Bob Gardes of Gardes Holdings to Alaska’s Cook Inlet basin as the soon-to-be new operator of the North Fork unit.
We hope this and the other acquisitions you are negotiating
will prove fruitful.
Bob Gardes
-
By ALAN BAILEY For Petroleum News
Work is still in progress in developing proposed regulations for the certifi-cation and governance of electric reliability
organizations in Alaska, Regulatory
Commission of Alaska Commissioner
Antony Scott told a public meeting of the
RCA on Dec. 9. The immediate purpose of
allowing ERO certification is to enable the
formation of an ERO for the Alaska
Railbelt electrical system, to enable more
unified management and planning for the
system. Ultimately, the expectation is to
minimize the cost of electricity for con-
sumers within acceptable levels of power
supply reliability.
The Railbelt utilities are in the process of
forming the Railbelt Reliability Council, or
RRC, to become an ERO for the Railbelt.
However, clarity is needed over the criteria
that the RRC needs to meet, to achieve cer-
tification. Governance and the structure of
an ERO board of directors is a particularly
difficult issue, given the importance of bal-
ancing the needs of various stakeholders,
including electricity consumers, electric
utilities and independent power producers.
Scott commented on the length of time
that it is taking to develop the regulations,
which are designed to enable the implemen-
tation of Senate Bill 123, a bill passed this
year to enable the formation of EROs in
Alaska. He talked about some modifica-
tions made to an earlier draft of the regula-
tions and encouraged members of the pub-
lic to comment on the concepts and word-
ing in the latest regulation draft. However,
he emphasized that the regulations are not
yet complete and have not yet reached the
stage of being published as proposed regu-
lations. The regulations have yet to be
reviewed by the state attorney general.
ERO responsibilities Scott emphasized that an ERO does not
directly supply services that are consumed
and is not, therefore, a utility that would
operate under a conventional certificate of
public convenience and necessity. An ERO
certificate would encompass ERO responsi-
bilities, which, in the latest draft of the reg-
ulations, would consist of the development
and enforcement of reliability standards for
the electrical system and for interconnec-
tion and non-discriminatory access to the
system; and the development of integrated
resource plans for the system.
There has been a suggestion that an
ERO could also administer an open access
tariff for the transmission system. But,
although the commission recognizes that,
given the small size of the Railbelt system,
there is an argument for cost efficiency by
including this function within an ERO, the
current regulation draft excludes this from
the scope of ERO responsibilities. If the
ERO’s role is to enforce standards, the ERO
should not at the same time be conducting
operations subject to the standards that it
enforces, Scott commented.
Another question revolves around
whether the ERO should have responsibili-
ty for oversight of economic dispatch
across the electrical system. Economic dis-
patch involves the continuous use of the
most efficient available power generation
capability. While the Southcentral Alaska
utilities are already in the process of jointly
implementing economic dispatch across
their service areas, expanding this arrange-
ment to other Railbelt regions would
require new transmission infrastructure,
involving system developments that are
unlikely to be carried out for some years.
So, there is time to resolve the further eco-
nomic dispatch issues at some time in the
future, Scott said.
The board structure A key issue revolves around the need to
ensure that an ERO board is appropriately
structured, and that the structure remains
appropriate after the ERO is certified, tak-
ing into account changes that may happen
in the business structure of the electrical
system. The revised draft regulations envis-
age the commission reviewing the board
structure as part of the ERO certification
process. A certificate, once granted, would
expire after six years, with the ERO being
required to have its own rules for ensuring
continuation of board balance during that
six year period.
The ERO would then have to apply for
re-certification when the certificate expires,
with the possibility at that point of some
other entity competing for the certificate.
The question of what constitutes a bal-
anced ERO board, representative of the var-
ious stakeholders in the electrical system, is
particularly difficult to adjudicate. At the
risk of becoming somewhat prescriptive,
rather than giving an ERO complete free-
dom to develop its own proposals, the new
regulation draft includes, for example, spe-
cific definitions of what the RCA would
recognize as valid groups of stakeholders to
be represented on the board, and criteria for
determining whether the board is appropri-
ately balanced.
For example, the new regulations draft
requires an odd number of board members,
no ERO employee can be a director on the
board, and board votes would need to come
from directors representing at least three
stakeholder groups. An ERO applying for a
certificate must also have procedures to
ensure that board decision are technically
sound, the draft says. l
6 PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020
Holiday Savings Offer
By KAY CASHMAN Petroleum News
On Oct. 1, operator Brooks Range Petroleum Corp., or BRPC, and Finnex LLC filed the
eighth annual plan of development for the
Southern Miluveach unit on behalf of the working
interest owners with Alaska’s Division of Oil and
Gas. Sustained oil production from the unit’s
Mustang field is planned by third quarter of next
year.
The eighth POD, which will run from Jan. 1 to
Dec. 31, 2021, takes up where work in the 8,960-
acre, five-lease, unit left off in December 2019.
Note: As previously reported in Petroleum News,
on Sept. 16 the Alaska Industrial Development and
Export Authority passed a resolution approving the
negotiation and execution of a debt settlement
restructuring agreement, or DSRA, and authorized
the sale of the Mustang oil field leases to Finnex.
Finnex is the special purpose vehicle, or SPV,
page 5
l F A C I L I T I E S
l E X P L O R A T I O N & P R O D U C T I O N
Vol. 25, No. 40 • www.PetroleumNews.com A weekly oil & gas newspaper based in Anchorage, Alaska Week of October 4, 2020 • $2.50
August ANS down marginally; Cook Inlet production off by 2%
see INSIDER page 11
Parks redo hangs on offshore O&G; Rivalry for oil investment heats up CONSERVING NATURAL RESOURCES
has “long been tied to and directly support-
ed by oil and gas development in the United
States,” Walter Cruickshank, Ph.D., acting
director of Interior’s Bureau of Ocean
Energy Management, wrote in a recent
release.
“This may seem counterintuitive to some,
but offshore energy development revenues
from qualified leases go right back into conservation initia-
tives throughout the United States via the Land and Water
Conservation Fund,” Cruickshank said in the story, which
was first published by The Vindicator.
Established in 1964, the LWCF supports federal, state and local land, water and wetlands purchases to expand public
access to public lands, “so more Americans can experience
see ICEBREAKER page 11
l E X P L O R A T I O N & P R O D U C T I O N
Russia’s new nuclear icebreaker completed, heads to Murmansk Construction of the Arktika, Russia’s newest nuclear ice-
breaker, has been completed and the vessel is heading from St. Petersburg to Murmansk, according to Rosatom State Atomic Energy Corp. Russia claims that the new vessel is the world’s largest nuclear icebreaker. Rosatom reports that the vessel is 173 meters in length, with a displacement of 33,540 tons. Two nuclear reactors power the vessel’s propulsion system. The ves-sel is the first of a series of four similar icebreakers, planned to
be built in a program referred to as “project 22220.”
The Barents Observer has reported that one of the vessel’s three electrical propulsion engines is broken and will need to be
replaced.
Russia’s particular focus is the operation of the Northern Sea route, the Arctic route around the north of the country, linking the Baltic Sea with South Korea and the north Pacific. With the continuing shrinkage of the Arctic sea ice extent and thinning of the ice, there is international interest in the potential for opening
Vol. 25, No. 2 October 2020
ArcticArcticCovering Arctic oil and gas operations and the logistics, construction and service firms that support them
Oil & Gas DirectoryOil & Gas Directory
Latest Arctic Directory released
BlueCrest’s 7th POD Maintain production; trident fishbone well on hold until prices firm up
By STEVE SUTHERLIN Petroleum News
BlueCrest Alaska Operating LLC will implement well work in order to main-
tain production under its seventh plan of
development for the Cosmopolitan unit, in
effect from Jan. 1, 2021, through Dec. 31,
2021.
In a Sept. 25 letter to the Alaska
Department of Natural Resources Division
of Oil and Gas, BlueCrest said plans in its sixth POD
to drill at least one trident fishbone well in 2020,
which were delayed due to COVID-19 oil market
disruptions, will remain on hold for 2021 “until the
current market environment improves.”
Each trident fishbone well, built on the
company’s success with its single fishbone
wells, will “provide the same amount of
reservoir contact as 21-27 individual
wells.” J. Benjamin Johnson, BlueCrest
Energy CEO and president told Petroleum
News in 2019.
A complete well plan stands ready for
the company’s proposed H10 trident well,
Johnson said in a Sept. 29 interview.
“It’s on indefinite hold. We’re ready to
go but we’re waiting to have some confidence in oil
prices,” he said. “It’s a moving target; the oil prices
are down but costs have also come down.”
The company said the pause in drilling has
Trump bolsters A2A Says will issue presidential permit for Alaska-to-Alberta import and export line
By GARY PARK For Petroleum News
From the time it was floated five years ago, the lat-est version of an Alaska-Alberta rail link has
been openly scorned by many and quietly given the
brush off by others.
For 130 years, various proposals have been made
for such a project to bolster imports and exports in
Alaska and Western Canada and have just as quickly
evaporated in the absence of financial backers.
But the idea keeps resurfacing as a serious plan to
move oil and other resources to and from the Pacific
Basin through Alaska.
The current proposal involves a venture by the
Alaska to Alberta Railway Development Corp., A2A.
In mid-2019 A2A announced it had reached an
agreement with the Alaska Railroad Corp. to develop
a joint operating plan to upgrade and extend the 515-
mile Alaska Railroad mainline between Seward and
North Pole.
Apparently the mega-undertaking has attracted
the attention of President Donald Trump, who
announced on Sept. 25 that he would issue a presi-
dential permit for the A2A project, a permit which the
president signed Sept. 28.
The plan involves building a 1,600-mile track
linking Anchorage, the Yukon, the Northwest
Territories and northern Alberta at a current cost esti-
mate of C$22 billion, with Alberta’s oil sands bitu-
men exports being carried by rail to Interior Alaska,
see MUSTANG PLAN page 9
see BLUECREST page 10
see A2A RAILWAY page 10
J. BENJAMIN JOHNSON
Mustang plan filed Oil production from the North Slope Southern Miluveach unit to start 3Q 2021
BRPC/Finnex said the Mustang project lost a year in its planned development schedule, “but the project remains fundamentally sound and (capable) of being brought to fruition.”
A special offer from Petroleum News!
Purchase a one year Petroleum News subscrip�on, and receive a gi� subscrip�on for just $1! Sign up today! CONTACT Renee Garbutt I 281-978-2771 [email protected] (Gift subscriptions must be used toward new subscribers. Special offer ends Dec. 31)
Fiord West without building a new
gravel pad, additional pipelines and
more roads, which would increase the
development footprint in an environ-
mentally sensitive area.
About 65 Doyon employees will
work on Rig 26. Workers will also be
needed for camps, transport and other
oilfield support services, ConocoPhillips
said. l
continued from page 4
COLVILLE PROJECTS
l U T I L I T I E S
RCA continues drafting ERO regulations Ensuring balance in governance over management of the Railbelt electrical system requires careful wording of certification rules
ENVIRONMENT & SAFETYHilcorp has Trading Bay slop oil release
The Alaska Department of Environmental Conservation reported Dec. 16 that
Hilcorp Alaska discovered a slop oil release at its Trading Bay Production Facility on
Dec. 15.
The product spilled, slop oil, consists of 80% crude oil and 20% water.
“Slop oil is defined as crude oil emulsified with water and solids rendering it a
waste stream that cannot be sold down the pipeline,” DEC said.
The release was 190 barrels from a leak in an underground line in the slop oil pro-
cessing system.
During a transfer of slop oil from Tank 4 to the slop oil tank, TK-9500, the operator
noticed that the tank level in the TK-9500 tank was not increasing proportionately to
see OIL RELEASE page 8
http://www.petroleumnews.com
-
By STEVE SUTHERLIN Petroleum News
T he U.S. Department of the Interior Bureau of Land Management has released the environmental assessment of
the application from Kaktovik Inupiat
Corp. to conduct seismic exploration within
the Coastal Plain of the Arctic National
Wildlife Refuge, according to a notice filed
Dec. 16 in the Federal Register.
The Marsh Creek East 3D survey is pro-
posed for the 2020-21 winter season, to
encompass approximately 350,000 acres of
private Alaska Native corporation and fed-
erally managed public lands in the eastern
portion of the ANWR 1002 Area.
BLM said public scoping for the appli-
cation and plan of operations generated
more than 100,000 comment submissions,
which were considered in the analysis.
Federal, state and tribal partners provid-
ed substantial input, said BLM Alaska State
Director Chad Padgett, adding, “It’s impor-
tant that we are responsive to our commu-
nity’s needs while providing a responsible
path forward for economic opportunities for
our North Slope communities.”
Seismic exploration over the last 12
years in the National Petroleum Reserve
Alaska and Cook Inlet — including lands
within the Kenai National Wildlife Refuge
— was analyzed through environmental
assessments, which determined there would
only be minimal impacts, BLM said.
“Modern seismic techniques in the
Arctic are well understood and have
evolved to include technologies and prac-
tices that minimize impacts” said BLM
Arctic District Manager Shelly Jones.
“These techniques continue to be success-
fully used in the National Petroleum
Reserve in Alaska, an environment similar
to the Coastal Plain, with no significant
impacts, including to wildlife, subsistence
or vegetation.”
SAE to conduct survey The proposed seismic exploration, spon-
sored by KIC, would be conducted by third-
party acquisition company SAExploration
Inc.
Surveys would begin when frost and
snow cover are at sufficient depths to pro-
tect tundra and would continue through the
winter season until tundra travel has been
closed, the assessment said. Mobilization to
the project area would begin in January,
after forward looking infrared radar surveys
had been conducted to detect polar bear den
sites.
Known polar bear den sites would be
avoided with a 1-mile buffer in all direc-
tions from the beginning of operations
through April or until a female with cubs
abandons an area.
A polar bear awareness training project
will be provided to all workers prior to the
start of operations, and polar bear aware-
ness refresher briefings will be a part of reg-
ular safety briefings.
BLM said the program area is little used
by overwintering caribou overall, so direct
impacts during winter activities would like-
ly be negligible. Summer cleanup activities
will be shifted to late summer to avoid cari-
bou calving times.
KIC has commissioned a cultural
resource study of historic and cultural
resources in the project area, the assessment
said. A licensed archaeologist will work
with the North Slope Borough, State of
Alaska and the refuge manager to review
existing records of all known existing cul-
tural studies in the project area. All cultural
or historic sites would be avoided and have
500-foot non-activity zone buffers placed
around them.
The Tax Cuts and Jobs Act of 2017
directed the secretary of the Interior,
through BLM, to establish and administer a
competitive program for the leasing, devel-
opment, production, and transportation of
oil and gas in and from the Coastal Plain.
The act also directed BLM to issue any
rights of way across the Coastal Plain for
exploration, development, and/or produc-
tion, including seismic exploration activi-
ties.
The EA and draft finding of no new sig-
nificant impact are available for a 14-day
review period, at:
https://eplanning.blm.gov/eplanning-
ui/project/2003258/510. l
l E X P L O R A T I O N & P R O D U C T I O N
KIC seismic environmental assessment out BLM EA finds no significant impact for Marsh Creek East 3D in ANWR 1002 Area proposed by Kaktovik Inupiat Corp. for this winter
PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020 7
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l E X P L O R A T I O N & P R O D U C T I O N
State of Alaska approves Jade 3rd POD Independent gets go ahead on latest annual plan of development for drilling Sourdough prospect in Point Thomson Area F, Tract 32
By KAY CASHMAN Petroleum News
O n Dec. 14, Alaska’s Division of Oil and Gas approved Jade Energy’s third plan of development for Area F, Tract 32, of the Point Thomson unit, which con-
tains BP’s mid-1990s Sourdough oil discovery where Jade
plans to drill an appraisal well in first quarter 2022.
The 2012 Point Thomson Unit Settlement Agreement
between the State of Alaska and certain Point Thomson
Unit working interest owners, including operator
ExxonMobil, required a separate plan of development for
Area F by Dec. 31, 2018. The settling working interest
owners were also required to maintain approved plans of
development for this area or relinquish the Area F acreage.
Independent Jade acquired a portion of working interest
in ADL 343112, a portion of but not the entire Area F, in
2018 and submitted a POD for that lease by Dec. 31 of that
year. Jade is not a party to the Point Thomson settlement
agreement, but the division determined that the POD it sub-
mitted satisfied the settling working
interest owner’s obligation to pro-
vide an Area F POD.
Jade’s plans for the 2020 POD
consisted of seismic data evaluation,
well design and permitting for
drilling in the winter of 2021-22,
conducting a bathymetric survey and
dredging the Point Thomson service
pier approach. These activities were
conducted, including the bathymetric
survey, however dredging was not attempted.
Jade’s plans for the 2021 POD include:
• Equipment and materials mobilization by snow trail to
Point Thomson in first quarter.
• Permitting for 2021-22 winter drilling.
• Mobilization planning to Point Thomson.
• Third bathymetric survey of the service pier
• Service pier approach dredging.
• Rig mobilization by barge to Point Thomson
“Plans beyond the next 12 month period remain to drill
a well to explore the Brookian interval. Drilling will likely
begin in early 2022,” the division said in its approval.
The decision is only for a general plan of development.
Specific field operations require separate approval in a Unit
Plan of Operations.
The 2022 POD is due Oct. 2, 2021, 90 days before the
2021 POD expires.
Erik Opstad, who oversees Jade’s operations in Alaska
and is a 50% owner, is a State of Alaska certified profes-
sional geologist who has worked the North Slope for 35
years, including a stint with BP in various roles and as a
principal and general manager of Savant Alaska. He cur-
rently heads up operating subsidiaries of 88 Energy in
Alaska.
See related story in the Nov. 8 issue of Petroleum
News. l
ERIK OPSTAD
l G O V E R N M E N T
Congress approves more US icebreakers Statute approves funding for construction of a second Coast Guard icebreaker, contracts for eventual construction of six vessels
By ALAN BAILEY For Petroleum News
T he Coast Guard Reauthorization Act, recently passed by Congress, includes provisions to continue the con-struction of new Coast Guard icebreakers, referred to as
polar security cutters. In 2018 Congress approved the even-
tual construction of six polar-class icebreakers, and in 2019
approved funding for the construction of the first of the ves-
sels. Currently the Coast Guard only operates two polar
capable icebreakers: the Healy, a medium duty icebreaker,
much used as a base for polar research, and the Polar Star,
which is a heavy icebreaker but is nearing the end of its
operational life.
The icebreaker construction program comes in the con-
text of Coast Guard concerns regarding its technical capa-
bility to fully conduct its role in a dynamic Arctic region.
Statute provisions The new legislation authorizes $745 million for the con-
struction of a second icebreaker, while maintaining the
existing contract for the first three of the new icebreakers
and authorizing the award of contracts for the construction
of the remaining three icebreakers, according to a press
release from U.S. Sen. Dan Sullivan, a co-author of the leg-
islation. Construction of the first of the icebreakers is
expected to start in 2021. Sullivan has been a strong advo-
cate for icebreaker construction.
U.S. Sen. Lisa Murkowski has also been an ardent sup-
porter of the icebreaker program.
“As a member of the Senate Appropriations Committee,
I have worked aggressively to help secure a robust fleet of
polar security cutters to meet our nation’s needs in the
Arctic, to protect our interests in the region, and to strength-
en our national security,” Murkowski said in a Dec. 13
release. “I’m proud of the progress that we have made to
help the U.S. strengthen its capacity and presence in the
Arctic as other Arctic and non-Arctic nations expand
theirs.”
Center for Arctic security studies The Coast Guard Reauthorization Act came as part of
the National Defense Authorization Act for Fiscal Year
2021. The National Defense Authorization Act also
includes a provision to form the Ted Stevens Center for
Arctic Security Studies, the first Department of Defense
regional center in the Arctic. The center will support
defense strategy objectives and policy priorities through a
“unique academic forum,” while also fostering strong inter-
national networks of security leaders, according to a release
by the Alaska Congressional Delegation. The specific loca-
tion of the center has yet to be determined.
“My friend, our late Sen. Ted Stevens, was not only a
steadfast advocate for Alaska, but he also fully recognized
the strategic importance of the Arctic to America's national
security,” said Congressman Don Young. “Establishing the
Ted Stevens Arctic Center for Security Studies has been one
of my highest priorities, and I am proud that our delega-
tion has always fought for its creation.” l
The icebreaker construction program comes in the context of Coast Guard concerns regarding its technical capability to fully conduct its role
in a dynamic Arctic region.
the decrease in the level in Tank 4.
After visual inspection the operator
observed oil under and around the edges of
the secondary containment liner. DEC said
upon discovering the leak the operator
immediately isolated tank TK-9500 and the
leaking line.
Nine Hilcorp personnel are on site
recovering the slop oil, DEC said, with 15
barrels recovered Dec. 15. Cook Inlet Spill
Prevention and Response has been activat-
ed to assist and is mobilizing personnel and
equipment to the site, DEC said.
Hilcorp and CISPRI personnel were
expected to fly out to the facility the after-
noon of Dec. 16 to assist the nine operators
already on site.
“Initial recovery will be conducted by
cutting the liner at the low spots to enable
suctioning out product above and below
the liner,” DEC said, with response, sam-
pling and waste disposal to be coordinated
with Hilcorp, DEC and the U.S. Coast
Guard.
—PETROLEUM NEWS
continued from page 6
OIL RELEASE
http://www.nanaworleyparsons.com
-
PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020 9
Oil Patch Bits
ADVERTISER PAGE AD APPEARS ADVERTISER PAGE AD APPEARS ADVERTISER PAGE AD APPEARS
Companies involved in Alaska’s oil and gas industry
A Acuren AES Electric Supply, Inc Afognak Leasing LLC Ahtna, Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11 Airport Equipment Rentals Alaska Dreams Alaska Frontier Constructors (AFC) Alaska Fuel Services Alaska Marine Lines Alaska Materials Alaska Railroad Alaska Steel Co. Alaska Tent & Tarp Alaska Textiles Alaska West Express Arctic Controls ARCTOS Alaska, Division of NORTECH Armstrong AT&T Avalon Development
B-F Bombay Deluxe BrandSafway Services Brooks Range Supply C & R Pipe and Steel Calista Corp. ChampionX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4 Chosen Construction Colville Inc. Computing Alternatives
CONAM Construction Cruz Construction Denali Universal Services (DUS) Doyon Anvil Doyon Associated Doyon Drilling Doyon, Limited EEIS Consulting Engineers, Inc. Egli Air Haul exp Energy Services F. R. Bell & Associates, Inc. Flowline Alaska Frost Engineering Service Co. – NW Fugro
G-M GCI GMW Fire Protection Greer Tank & Welding Guess & Rudd, PC HDR Engineering, Inc. ICE Services, Inc. Inlet Energy Inspirations Judy Patrick Photography Little Red Services, Inc. (LRS) LONG Building Technologies Lounsbury & Associates . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3 Lynden Air Cargo Lynden Air Freight Lynden Inc. Lynden International Lynden Logistics
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Q-Z
Raven Alaska – Jon Adler Resource Development Council SeaTac Marine Services Security Aviation Shoreside Petroleum Soloy Helicopters Sourdough Express . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2 Strategic Action Associates Tanks-A-Lot Weston Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3 Wolfpack Land Co.
All of the companies listed above advertise on a regular basis with Petroleum News
Denali Universal Services announces new leadership Denali Universal Services said Dec. 14 that it is announcing that
Bob Kean, who has spent the last 20 years with DUS, is retiring after a long and esteemed career of both public and private serv-ice, effective Dec. 31. Kean has made significant contributions to the growth of DUS during his tenure and will continue to serve DUS and Sodexo in an advisory role. DUS wishes Kean well in his retirement and thanks him for his many contributions.
Following Kean’s departure, DUS is pleased to announce that Maria Bourne has been promoted to president, effective Jan. 1. Over the past five years as senior vice president of operations and chief financial officer, Bourne has been responsible for DUS’s finan-cial management. Her responsibilities included supervising opera-tional execution, assisting in company growth, facilitating development, and supervising internal management. Along with her Bachelor of Business Administration in accounting from the University of Alaska, Bourne is a certified public accountant and has spent over a decade in senior financial management positions. Prior to DUS, she worked at KPMG, where her work focused on auditing, advisory, and valuation services.
“I am grateful to have spent 20 years with this company and am very proud of what the DUS team has accomplished together,” said Kean. “As the future unfolds, I have great confidence that DUS is in terrific hands for future success. Maria Bourne has been prepar-ing for this and the timing is right for her to transition into the role as president of DUS.”
Bison relocate to Sitkalidak Island with Lynden’s help As reported by Lynden News Dec. 8, earlier this year the Alutiiq Tribe of Old Harbor,
Alaska, was awarded three bison bulls from Yellowstone National Park to improve the genetic diver-sity of its Sitkalidak bison herd. The catch: the bison required transport from Montana to Seattle, from Seattle to Anchorage and from Anchorage to Homer Spit. The final destination required a boat ride to Sitkalidak on Kodiak Island.
“I was informed that on special occasions Lynden Transport may transport livestock,” said Cynthia Berns, vice president of community affairs for the Old Harbor Native Corp. “So, I called Paul Friese in Anchorage.”
Paul Friese, vice president of Alaska sales for Lynden Transport, responded to the call with the usual can-do attitude. Gathering all the details, he quickly put the team in motion. Lynden driver Clay Bonty met the FedEx plane in Anchorage, carefully loaded the special 20-foot container containing the three bison and headed to Homer. “This was a very spe-cial project,” Paul says. “We were happy to be involved and assist the Alutiiq Tribe.”
The transfer was a historic moment in returning Yellowstone bison to tribal lands. These particular animals are important to tribes because they are the genetically pure descen-dants of the bison that tribal ancestors lived with. In the case of the Sitkalidak herd, the new bulls will introduce genetic diversity for herd survival.
“Our herd is managed to provide food security for our community of 230 residents and tribal members throughout the state,” Cynthia explained. “In 2017, DNA testing was con-ducted on the herd, and it was suggested that we integrate new genes into the herd for long-term health and survival.”
The bulls are settled in and doing well. For more information visit info.lynden.com/blog.
CO
URT
ESY
LY
ND
EN
MARIA BOURNE
allow financial institutions to benefit handsomely from
Alaska’s financial activities on one hand, while working
against our interests on the other.”
Dunleavy’s action aims to put some financial teeth into
the consequences for lending discrimination across a
wide, strategically and financially important swath of the
state.
The federal Office of the Comptroller of the Currency
has put offending banks on notice that red-lining arctic or
energy lending is inconsistent with the Dodd–Frank Act
mandate.
An OCC investigation found that major banks had
indeed engaged in such discrimination during 2019 and
2020. In response, the office proposed a rule Nov. 20
directing fair access to banking services.
The Goldman Sachs Group Inc. initiated the controver-
sy in late 2019, announcing it would decline to finance any
new arctic oil exploration or development. Other major
U.S. and international banks — including JPMorgan
Chase & Co., Citigroup Inc., Wells Fargo & Co. and Swiss
bank UBS — followed with similar announcements.
Dunleavy said oil and gas exploration in the Arctic has
benefitted Alaska and the country with “thousands of jobs
and billions of dollars in revenue.”
“Alaska’s environmental standards for oil and gas
development are widely considered among the best in the
world,” Dunleavy said. “Other states, and even other
countries have reached out to the State of Alaska to learn
how to explore and produce oil and gas reserves safely and
responsibly.”
The OCC said large banks influence the price of finan-
cial services, and only the largest have the diversified bal-
ance sheets and sophisticated risk management systems to
serve certain industries.
“It is fair to place particular responsibilities on the
largest banks because their systemic importance often
results in their receiving assistance and favorable treat-
ment from the government during periods of financial dis-
tress,” the OCC said.
“If a group of financial institutions want to make a
political statement with their investment strategy, that is
their prerogative — but if Alaska does not have a robust
oil and gas industry our future is not bright,” Dunleavy
said. “It is my job to protect Alaska and its economic
future.”
—STEVE SUTHERLIN
continued from page 1
ARCTIC FINANCING“It is fair to place particular responsibilities on
the largest banks because their systemic importance often results in their receiving
assistance and favorable treatment from the government during periods of financial
distress,” the OCC said.
Contact Steve Sutherlin at [email protected]
-
10 PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020
She said the revenue forecast for fiscal year 2021 is
based on ANS crude oil prices averaging $45.32 per bar-
rel, rising to $48 for FY 2020 and — based on inflation
— reaching $57 per barrel by FY 2030.
“The oil price forecast is based on future market
prices and reflects expectations of sluggish oil demand
and ample global supply over the long term,” Mahoney
said.
Revenues from oil and gas, which powered state unre-
stricted general fund spending for years, have been sup-
planted, as production declines, by investment dollars,
primarily from the Alaska Permanent Fund. In FY 2020,
investment provided $3 billion in unrestricted funds,
66%, compared to petroleum at $1.1 billion, 24%.
(Petroleum also contributed some $600 million, 15%, to
restricted state revenues, which collectively accounted
for 48% of state revenue, $4.1 billion, compared to $4.5
billion in unrestricted.)
In the RSB, the department said petroleum revenue —
production tax, royalties, property tax and corporate
income tax — is projected to provide between 19% and
22% of unrestricted revenue over the next 10 years.
ANS price, production ANS oil prices averaged $52.12 per barrel in FY
2020. The department noted that it changed how oil
prices are forecast in 2019, with the short-term price
forecast — for the current and next fiscal year —
“derived from futures market expectations for Brent
crude.” Beyond that, “the price forecast is held constant
in real terms, increasing with inflation.”
ANS crude oil production averaged 471,800 barrels
per day in FY 2020 — a volume which excludes 10,000
bpd of natural gas liquids from Prudhoe that are sent to
Kuparuk to be used in enhanced oil recovery. Those bar-
rels, Revenue said, are counted by the Alaska Oil and
Gas Conservation Commission but are not counted by
Revenue when they are produced at Prudhoe to avoid
double counting when the barrels are ultimately pro-
duced at Kuparuk.
Production is forecast to average 477,300 bpd in FY
2021 and then decline to 439,600 bpd in FY 2022, after
which “production is forecast to stabilize and increase to
481,800 barrels per day by the end of the 10-year fore-
cast period.”
Expenditures, revenues Allowable oil and gas lease expenditures in FY 2020
were an estimated $6 billion statewide, $5.5 billion of
that on the North Slope, Revenue said. For FY 2021, the
expectation is that those will decrease to $4.3 billion
statewide, $3.9 billion on the North Slope.
Expenditures are expected to increase in FY 2022 and
FY 2023, “as activity increases at existing fields and as
companies make expected investments in new develop-
ments,” including billions to bring Pikka and Willow into
production.
ANS transportation costs averaged $8.16 per barrel in
FY 2020 and are expected to average $9.21 in FY 2021
and $9.91 in FY 2022. “Transportation costs are subtract-
ed from the ANS price to form the basis for tax and roy-
alty calculations,” Revenue said.
Total petroleum revenue — unrestricted and restricted
— was $1.7 billion in FY 2020, Revenue said, down
$915 million, 34.9%, from FY 2019, and is projected to
be $1.187 billion in FY 2021, down $518 million, 30.4%,
dropping to $1.090 billion in FY 2022, down 8.1% from
the previous fiscal year.
Production forecast In its 10-year production forecast, broken out by
North Slope fields and Cook Inlet, Revenue sees
statewide production rising from 485,300 bpd in FY
2020 to 488,900 bpd in FY 2021, dropping off to
450,900 bpd in FY 2022, and then rising to 458,200 bpd
in FY 2023, and climbing fairly steadily to 494,100 bpd
in FY 2030.
The biggest contributors to the increase by FY 2030
are fields which fall in the department’s “other” category
— projects under development and evaluation outside of
existing production areas. The list includes Alkaid,
Guitar, Narwhal, Pikka, Placer and Smith Bay. Pikka is
the largest of these currently under development. The
“other” category grows from no production in FY 2021,
to nominal volumes in FY 2022 and 2023, is estimated at
9,000 bpd for FY 2024, 23,600 bpd in FY and grows
steadily thereafter to an estimated 96,500 bpd in FY
2030.
The other large growth area is the National Petroleum
Reserve-Alaska, which includes GMT1, GMT2, Willow
and Umiat. Production is forecast at 2,200 bpd in FY
2021, growing to 19,900 bpd in FY 2023, 41,400 bpd in
FY 2024, with volumes up and down thereafter but esti-
mated at 55,000 bpd in FY 2030.
Most current producing areas have reduced produc-
tion over the 10-year period, but the Kuparuk satellites
— Meltwater, NEWS, Nuna-Torok, Tabasco, Tarn and
West Sak — estimated at 30,900 bpd in FY 2021, drop
slowly through FY 2027 and then increase to 33,600 bpd
in FY 2030.
—KRISTEN NELSON
continued from page 1
REVENUE FORECAST
while his Environment Minister Jonathan Wilkinson said
the C$170 goal has yet to be negotiated with the
provinces and territories.
“We know that Canadians understand they can no
longer be free to pollute anywhere in the country,” he said.
The tax is part of a C$15.2 billion plan to help fund
development of hydrogen, electric vehicle infrastructure
and incentives for existing industries to decarbonize their
operations.
The announcement will be followed, likely before the
end of 2020, with a Clean Fuel Standard that will stipulate
that fuel providers and refiners must reduce their GHGs
by 12% below 2016 levels by 2030, positioning Canada to
drive innovation and attract investment.
Goal 30 million tons The goal for the CFS is a 30 million metric ton reduc-
tion in carbon emissions, helping put Canada on track to
achieve its global climate goals.
On the carbon tax plan, the Canadian Association of
Petroleum Producers said it was analyzing the announce-
ment to “fully understand its implications” for the industry
It said new technologies and innovation “will play a
major role in ensuring Canada can meet its domestic emis-
sions reduction goals” while contributing to a lowering of
global carbon output “by providing lower emission natural
gas and oil to world markets.”
Tristan Goodman, president of the Explorers and
Producers Association of Canada, said Trudeau’s Dec. 11
announcement will give his mid-sized member companies
what they have been looking for — a timeline and price on
carbon taxes.
He said that stability will allow the sector to “imple-
ment some green technologies,” but he expressed some
unease about whether consumers will be able to absorb the
higher costs.
Goodman said the exemption for natural gas, as well as
other gaseous fuels, is “a wise, sensible decision” that will
prevent natural gas prices from heading “significantly
higher.”
Cost per family Trevor Tombe, an economist at the University of
Calgary, said the C$170 tax will raise the cost of fuel taxes
by 37.57 cents per liter over the next decade.
He said the tax hike would cost an Alberta family of
four C$3,200 a year, which will be rebated through quar-
terly checks or a direct deposit to bank accounts.
Tombe said that if Alberta chose to create its own car-
bon tax it would be able to use the rebate money as it saw
fit, including paying down its deficit.
Alberta Environment Minister Jason Nixon said that
ratcheting up the federal carbon tax (currently C$30 per
metric ton) is “another attack on Alberta’s economy and
Alberta’s jurisdiction” over the use and taxation of its nat-
ural resources.
He said Alberta is already making headway on pro-
grams to reduce methane emissions and promote initia-
tives to develop hydrogen and capture carbon emissions.
The Supreme Court of Canada is expected to rule soon
on a challenge by Alberta, Saskatchewan, Ontario and
Newfoundland that argues the existing federal carbon tax
is an “unconstitutional” overreach by the Trudeau govern-
ment.
If the court rules against the federal government,
Trudeau may be forced back to the drawing board on the
climate plan.
—GARY PARK
continued from page 1
CARBON TAX
Dec. 16 said that the Federal Reserve would also contin-
ue to add stimulus to the economy.
Essentially the Fed wants to see sustained inflation
above its target — before it considers ending emergency
policies. It committed to continue buying bonds until the
economy reaches full employment and inflation stays at
2%.
The Fed will continue at least $120 billion a month in
bond purchases, but it did not — as some investors were
expecting — extend the duration of the bonds.
The Fed also voted, as expected, to maintain short-term
borrowing rates near zero.
The stimulus news bolstered a rally sustained over the
past few weeks by a wave of good news on COVID-19 vac-
cine approvals, and news that the first doses of the vaccines
were being delivered throughout the United States and else-
where in the world.
The COVID-19 vaccine rally has been held in check to
an extent by concerns that increasing lockdowns due to
widespread spikes in coronavirus infections may put a
damper on demand recovery as the winter season plays out.
Most analysts in fact now do not expect vaccines to have
a major impact on the demand scenario until mid-2021.
OPEC trims demand projections World oil demand projections by the Organization of the
Petroleum Exporting Countries for 2020 held steady month
over month, according to the OPEC Monthly Oil Market
Report, published Dec. 13.
Demand was adjusted down a marginal 9.77 million bar-
rels per day from the cartel’s November assessment.
The December report was the first assessment released
by OPEC since the organization and its affiliated producing
countries, known as OPEC+, agreed to a 500,000-bpd pro-
duction increase starting on Jan.1. Rather than instituting a
scheduled increase of 2 million bpd, the group moderated
its increase due to recent slower-than projected demand
recovery.
Demand in Organization for Economic Cooperation and
Development countries was revised down 0.18 million bpd,
mainly due to lower transportation fuel demand in the
United States and OECD Europe.
OCED woes were offset by an upward revision for non-
OECD demand, of 0.16 million bpd.
A surprising pop in oil demand from China — staging
steady recovery in various economic sectors — and a bit of
demand pull from India support the rising assessment.
Total oil demand is estimated to reach 89.99 million bpd
in 2020.
For 2021, world oil demand growth is revised lower by
0.35 million bpd, to growth of 5.90 million bpd. Total oil
demand is projected to reach 95.89 million bpd in 2021.
Non-OPEC liquids production in 2020 was revised
lower by 0.08 million bpd, month over month, to average
62.67 million bpd. The drop owed to downward revisions in
Brazil, the United States, the UK and Norway, and was par-
tially offset by upward revisions to production in Russia and
Canada.
For the year, oil supply declined in Russia, the U.S. and
Canada. Production in Norway, Brazil, China and Guyana
is estimated to have grown.
Non-OPEC supply for 2021 was adjusted down by 0.1
million bpd, now forecast to grow by 0.85 million bpd to
average 63.52 million bpd — mainly due to downward
revisions in Russia’s output.
The main drivers for supply growth are expected to be
the United States, Canada, Brazil and Norway.
OPEC crude oil production in November increased by
0.71 million bpd, month over month, to average 25.11 mil-
lion bpd, according to secondary sources. l
continued from page 1
OIL PRICES
Contact Steve Sutherlin at [email protected]
-
Alaska is “we take advantage of North
Slope best practice and all those that have
come before us, so as you look at Pikka it
will be the next generation oil field. …
The facilities are designed for even lower
greenhouse gas emission intensity and a
small footprint,” Elmer said. “When you
compare Pikka to similar sized fields
around the world its (greenhouse gas
emissions are) extremely low — it’s
going to be in the top quartile.”
“Alaska, as we know, has one of the
most robust regulatory environments in
the world. We don’t flare for production
on the North Slope. There are a lot of
things that are done to really drive a lower
environmental impact,” he said.
Bill Armstrong agrees Bill Armstrong, the man whose com-
pany brought Oil Search to the North
Slope, agrees with Elmer’s comments.
“People misunderstand Arctic devel-
opment; they picture offshore production
platforms in an iceberg rich sea with
whales swimming about or big drilling
rigs in a gorgeous, pristine mountain
landscape. North Slope Arctic develop-
ments are on a flat, barren landscape with
nearby underutilized infrastructure
already in place,” Armstrong told
Petroleum News in a Dec. 8 email.
Equivalent to 3 moon missions In addition to drilling two exploration
wells with three penetrations and making
three major discoveries (see part one of
this story) this past winter, Elmer talked
about Oil Search’s massive gravel lay for
Phase 1 of its Pikka development.
“The gravel lay was one of the most
significant gravel lays that has been done
on the North Slope in the last 20 to 25
years. If you looked at the scope of it, we
built 200 miles of ice roads, 111 acres of
ice pads. We had 17 camps on the Slope
and 1,100 people to execute on both the
civil works and the two exploration
wells,” he said.
“As part of the civil work we laid
almost two and a quarter million cubic
yards of gravel. We used two mine sites to
do it, so it was greater than 50,000 truck-
loads, so if you lay that out, we actually
did the equivalent of three moon mis-
sions.”
“There were a lot of miles driven and
I’m very proud to say that the safety
record we achieved was just outstanding.
So not only did we get the roads down,
we got three pads. We also had to install
one bridge over the Miluveach River,”
Elmer said.
As for North Slope activities this win-
ter, he said Dec. 3 that “most of our activ-
ities next year will be in the engineering
area Now that we’ve got the civil work
done and our pads and our roads are down
we are looking to take FEED on the proj-
ect in the first quarter. We hope to get to a
final investment decision by the end of
the year.”
“So, most of 2021 will be to support
that FID decision,” Elmer said. l
Editor’s note: See part 1 of this story in last week’s edition of Petroleum News.
PETROLEUM NEWS • WEEK OF DECEMBER 20, 2020 11
Association (case in which the National
Audubon Society is the lead plaintiff).
“The Department of the Interior and
BLM rushed their environmental review
and adopted an extensive and harmful
leasing program that is inconsistent with
numerous laws and regulations,” plain-
tiffs’ attorneys said in the Gwich’in case
Plaintiffs in one suit, represented by
Trustees for Alaska, are the Gwich’in
Steering Committee and numerous envi-
ronmental organizations, among them the
Alaska Wilderness League, Canadian
Parks & Wilderness Society-Yukon,
Friends of Alaska National Wildlife
Refuges and the Alaska Environmental
Center.
Plaintiffs in the other are the National
Audubon Society et al., represented by
attorneys with Earthjustice and the
Natural Resources Defense Council.
The suits ask rulings by Jan. 6, the date
set for the Coastal Plain lease sale.
In the Gwich’in Steering Committee
case, plaintiffs argue for a temporary
restraining order and preliminary injunc-
tion