ment including nine wells—six in Taurus and three in Libra—
and a 42-km tieback to the existing onshore processing facility
where gas enters the Egyptian grid via a nearby export pipeline.
Commissioning of all nine wells and ramp up to stable operations has been completed.
The West Nile Delta development, which encompasses the
North Alexandria and West Mediterranean Deepwater offshore
concession blocks, is being developed as two separate projects.
When fully on stream in 2019, combined production from both
projects is expected to reach nearly 1.5 billion bcfd, equivalent
to about 30% of Egypt’s current gas production. All gas produced will be fed into the national gas grid.
BP says the second West Nile Delta project, involving development of Giza, Fayoum, and Raven fields, also is ahead of
schedule and under budget. The project will involve 12 wells
and two deepwater long-distance subsea tiebacks to shore. Fluids will be processed through an onshore plant modified for
Giza and Fayoum and integrated with a new adjacent onshore
plant for Raven. Production from Giza, Fayoum, and Raven is
expected to start in 2019.
BP is operator of the West Nile Delta project with 82.75%
interest. DEA Deutsche Erdoel AG holds the remaining 17.25%.
Eni begins gas production from Jangkrik project
Eni SPA has started gas production from the Jangkrik development project in the deep waters offshore Indonesia. The project
comprises Jangkrik and Jangkrik North East gas fields on the
Muara Bakau block of the Kutei basin in the Makassar Strait.
Production from 10 deepwater subsea wells connected to the
Jangkrik floating production unit (FPU) will gradually reach
450 MMscfd, or 83,000 boe/d. Once processed onboard the
FPU, gas will flow via a 79-km pipeline to an onshore receiving
facility and then through the East Kalimantan transportation
system, finally reaching the Bontang gas liquefaction plant.
Production start-up comes less than 3½ years after project
sanction. Gas volumes from Jangkrik will supply the Indonesian market as well as the LNG export market.
The Jangkrik FPU may also be used as a development hub
for Eni’s Merakes gas discovery, which Eni says could start production in the next 2 years.
Eni subsidiary Eni Muara Bakau BV is operator of the Muara
Bakau production-sharing contract with 55% interest. Partners
are Engie E&P subsidiary GDF SUEZ Exploration Indonesia BV
with 33.334% and PT Saka Energi Muara Bakau with 11.666%.
Activities are carried out in coordination with SKK Migas, the
entity representing the Indonesian government.
Statoil to add third platform at Peregrino Phase II
The Peregrino Phase II field development will access new acreage
out of reach of its current two wellhead platforms and floating production, storage, and offloading vessel. The contract was let in June
2016 (OGJ Online, June 28, 2016). According to Heerema Fabrication Group, the 8-legged jacket will include a wellhead platform
with a drilling unit (WHP-C) tied back to the existing FPSO.
The 135-m Peregrino jacket will have a 66 x 53-m footprint,
weighing 9,300 tonnes (excluding 12 piles). The company,
which is constructing the jacket on behalf of South Atlantic
Holding BV on behalf of Statoil ASA, will start construction in
November at the Heerema yard in Vlissingen, the Netherlands.
The installation is expected to sail away in October 2019.
The jacket will serve as a foundation for the topside, which
will include the drilling and process facilities, utilities, power
generation, living quarters, and a helideck with a design operational weight of 25,000 tonnes. The jacket also is designed
for fresh water storage to assist drilling caissons for submerged
pumps connected to the storage tanks.
Peregrino Phase II development will add 21 wells to the
field, including 15 development wells and 6 water-injection
wells. The third wellhead platform will be installed in 120 m
of water and is expected to start production by yearend 2020.
Peregrino Phase II is estimated to add recoverable resources of
250 million bbl of oil by the end of 2040, when the concession
period ends (OGJ Online, Feb. 27, 2015).
PROCESSING QUICK TAKES
Shell, Aramco finalize separation of Motiva assets
Saudi Aramco and Royal Dutch Shell PLC have completed their
previously announced deal to divide up assets, liabilities, and
businesses of their US-based refining and marketing joint venture Motiva Enterprises LLC (OGJ Online, Mar. 7, 2017).
Finalized on May 1, the transaction follows Aramco subsidiary Saudi Refining Inc. (SRI) and Shell US downstream affiliate
SOPC Holdings East LLC’s Mar. 6 signing of binding definitive
agreements to end the partnership, Shell said.
Shell now holds sole ownership of the 235,000-b/d Norco
refinery—where subsidiary Shell Chemical LP already operates
a petrochemical plant—and the 242,250-b/d Convent refinery,
which Motiva previously announced will be integrated to create
the Louisiana Refining System (OGJ Online, Aug. 12, 2016).
Additionally, Shell remains owner of 11 distribution terminals as well as Shell-branded markets in Alabama, Mississippi,
Tennessee, Louisiana, a portion of the Florida Panhandle, and
the US Northeast, all of which are now fully integrated with
Shell’s North American downstream business, the company said.
Alongside retaining 24 distribution terminals and the Motiva
name, SRI has taken 100% ownership of the 600,000-b/d Port
Arthur, Tex., refinery and maintains an exclusive, long-term
license to use the Shell brand for gasoline and diesel sales in
Georgia; North and South Carolina; Virginia; Maryland; Washington, DC; the eastern half of Texas; and much of Florida.
Petrobras to shed Texas refinery
Petroleo Brasileiro SA (Petrobras) has added the proposed sale
of subsidiary Pasadena Refining Systems Inc.’s (PRSI) 100,000-
b/d refinery in Pasadena, Tex., to a revised divestments portfolio recently approved by the company’s executive board following a mid-March decision on the divestment plan from Brazil’s