E&P Notes (February 2021)
Authors: JPT staff _ 
Published: January 2021

Jersey Oil and Gas Unearths Wengen Prospect
The Greater Buchan Area (GBA) now has four drill-ready prospects to add to discoveries already slated for development.
In a new subsurface evaluation, Jersey Oil & Gas, a British-independent North Sea-focused upstream oil and gas company, has uncovered a new prospect, named Wengen, to complement its Verbier Deep, Cortina NE, and Zermatt drill-ready prospects. The four are estimated to host some 222 million bbl of P50 prospective resources, all in the immediate vicinity of Jersey’s planned GBA production facility.
The consolidated Greater Buchan venture comprises Buchan field (80 million bbl), Verbier (c25 million bbl), J2 (c20 million), and Glenn (14 million).
The new prospect, located in License P2170, is directly west of the Tweedsmuir field and should host some 62 million bbl of potential resources (P50), with the probabilistic range set at 31 million bbl at P90 (higher confidence) and 162 mil-lion for P10 (lower confidence). Probability of geological success is 22% for the prospect.
Contractor Rockflow previously estimated the recoverable resources in the GBA at 94.7 million bbl, including the parts within P2170.
In late November, Jersey announced it is taking full ownership of License P2170, which hosts most of the Verbier discovery, as part of the GBA.
In March, Jersey told investors the project is fully funded and that it intends to take the project to potential industry partners via a farm-out process.
An exploratory drilling campaign is being planned for 2022.
Jordan Finds “Promising” Gas Reserves Near Iraq Border
Jordan’s majority state-owned National Petroleum Company (NPC) has discovered “promising” natural gas in the Risha gas field along its eastern border with Iraq.
Risha makes up nearly 5% of the kingdom’s consumption of natural gas of around 350 MMcf/D for power generation, Jordanian officials said.
The flow of new gas supplies will raise the productivity of the gas field and help Jordan cut dependence on oil imports to fuel its power sector and industries.
The country, which now imports over 93% of its total energy supplies, is burdened by a $3.5-billion annual bill, comprising almost 8% of Jordan’s GDP.
Although British supermajor BP abandoned the eastern desert area in 2014 after investing over $240 million, Jordanian exploration has stepped up since 2019, boosting quantities by at least 70%, Mohammad al Khasawneh, head of NPC, said.
An ambitious 10-year energy plan unveiled in 2019 aims to secure nearly half of the country’s electricity generation from local energy sources com-pared to a current 15%, according to Iraq Energy Minister Hala Zawati.
The plan is meant to diversify local energy sources by expanding investments in renewable and oil shale to reduce costly foreign fuel imports, Zawati added.
ExxonMobil Discovers Hydrocarbons Offshore Suriname
ExxonMobil and Petronas have discovered several hydrocarbon-bearing sandstone zones with good reservoir qualities in the Campanian section of the Sloanea-1 exploration well on Block 52 offshore Suriname, adding to ExxonMobil’s finds in the Guyana-Suriname basin. The well was drilled by operator Petronas.
ExxonMobil said in November that it is prioritizing near-term capital spending on advantaged assets with the highest potential future value.
Maersk Drilling reported in early July that it had secured the Maersk Developer from Petronas subsidiary PSEPBV in a $20.4-million one-well exploration con-tract offshore Suriname. The semisubmersible rig drilled the Suriname-Guyana basin well to a total depth of 15,682 ft.
“We are pleased with the positive results of the well,” Emeliana Rice-Oxley, Petronas’ vice president of upstream exploration, said. “It will provide the drive for Petronas to continue exploring in Suriname, which is one of our focus basins in the Americas.”
Block 52 covers an area of 1.2 million acres and is located approximately 75 miles offshore north of Paramaribo. The water depths on Block 52 range from 160 to 3,600 ft.
ExxonMobil E&P Suriname BV, an affiliate of ExxonMobil, holds 50% interest in Block 52. PSEPBV is operator and holds 50% interest.
CNOOC Starts Production on Penglai 25-6 Oil Field Area 3 Project
China National Offshore Oil Corporation (CNOOC) announced on 14 December that its Bohai Sea Project - the Penglai 25-6 oil field area 3 - has started production ahead of schedule.
The biggest offshore oil field and the second biggest oil field in China, the Penglai is located in the south central Bohai Sea, with average water depth of about 27 m. In addition to fully utilizing the existing processing facilities of Penglai oil fields, the project has built a new wellhead platform and plans 58 development wells, including 38 production wells and 20 water-injection wells. The project is expected to reach its peak production of approximately 11,511 B/D of crude oil in 2023.
Six successful appraisal wells were also drilled, which confirmed the presence of hydrocarbons in reservoirs located with-in Miocene, Lower Minghuazhen, and Guantao sandstones.
The Penglai 19-3 oil field is located in Block 11/05 of Bohai Bay, approximately 235 km southeast of Tanggu. The production-sharing contract for block 11/05 was signed between CNOOC and ConocoPhillips China (COPC) in December 1994; the field was discovered jointly by CNOOC and COPC in 1999.
The oil field was developed in two phases. Phase I production started in December 2002; production from the wellhead platform C, which is tied back temporarily to the production facilities of Phase I, began in June 2007.
Since June 2020, CNOOC has announced five production startups: the Jinzhou 25-1 oilfield 6/11 area project, the Liuhua 16-2 oilfield/ 20-2 oil-field joint development project, the Nan-bao 35-2 oilfield S1 area project, the Luda 21-2/16-3 regional development project, and the Qinhuangdao 33-1S oilfield phase-I project.
In Q3 2020, CNOOC achieved a total net production of 131.2 million BOE, which the company said represented an increase of 5.1% year over year. Production from China was said to have increased by 10.4% year over year to 88.6 million BOE.
In November, CNOOC revealed that the Liuhua 29-1 gas field had begun production; in September, the company said the Bozhong 19-6 condensate gas field pilot area development project had also begun.
Operator CNOOC holds 51% interest while COPC holds 49% interest in the Penglai 25-6 oilfield area 3 project.
Equinor’s Snorre Expansion Project Starts Ahead of Schedule, Below Cost
Work began in December on the Snorre Expansion Project in the southern part of the Norwegian Sea. This increased-oil-recovery project will add almost 200 million bbl of recoverable oil reserves and help extend the productive life of the Snorre field through 2040.
The expansion project is proposed in blocks 34/4 and 34/7 of the Tampen area, approximately 124 miles west of Florø in the Norwegian North Sea.
“I am proud that we have managed to achieve safe startup of the Snorre Expansion Project ahead of schedule in such a challenging year as 2020. In addition, the project is set to be delivered more than NOK 1 billion below the cost estimate in the plan for development and operation,” Geir Tungesvik, Equinor’s executive vice president for technology, projects, and drilling, said.
Originally scheduled to come onstream in the first quarter of 2021, the project comprises 24 new wells divided into six subsea templates, drilled to recover the new volumes. Bundles connecting the new wells to the platform have been installed, in addition to new risers. The project also includes a new module and modifications on Snorre A.
In December 2017, Equinor submitted a modified plan for development and operation of the field. With the expansion, the recovery factor will increase from 46 to 51%, representing significant value for a field with 2 billion bbl of recoverable oil reserves.
Wind power will supply about 35% of the power requirement for the Snorre and Gullfaks fields. The Hywind Tampen project, featuring 11 floating wind turbines, should start up in Q3 2022.
The investments in the expansion project total NOK 19.5 billion (2020 value). The project has had substantial spin-off effects for the supply industry in Norway, particularly in eastern Norway and in Rogaland.
The Snorre field partnership comprises Equinor (operator) 33.27%, Petoro 30%, Vår Energi 18.55%, Idemitsu 9.6%, and Wintershall Dea 8.57%.
Petrobras To Sell Entire Stake in Onshore Field of Sergipe
Petrobras on 11 December signed a contract with Energizzi Energias do Brasil to sell its entire stake in the onshore field of Rabo Branco, located south of the Carmópolis field in the Sergipe-Alagoas Basin, Sergipe state. The Rabo Branco field is part of the BT-SEAL-13 concession.
The $1.5-million sale is in line with Petrobras’ strategy to cut costs and improve its capital allocation, to focus its resources increasingly on deep and ultradeep waters.
The average oil production of the field, from January to October 2020, was 138 B/D.
Energizzi Energias do Brasil will own 50% stake in the Rabo Branco field; operator Produção de Óleo e Gás (Petrom) holds the remaining 50%.
On 10 December, Petrobras closed the divestiture of its full ownership in four onshore fields at the Tucano Basin site in the state of Bahia. Petrobras sold its entire interest to Eagle Exploração de Óleo e Gás (Eagle).
Petrobras earned $2.571 million from this sale, in addition to the $602,000 that the company received at the time of signing the sale contract, for a total of $3.173 million.
BP, Reliance Announce First Gas From Asia’s Deepest Project
Oil-to-telecom conglomerate Reliance Industries Limited (RIL) and BP have started production from India’s first ultradeepwater gas project, the first of three such projects in the KG D6 block.
The R Cluster gas field is located off the east coast of India, about 60 km from the existing KG D6 control-and-riser platform (CRP), and comprises a subsea production system tied back to the CRP via a subsea pipeline. It is the deepest offshore gas field in Asia at a depth greater than 2000 m.
The companies’ next project, the Satellites Cluster, is expected to come on stream this year, followed by the MJ project in 2022. These projects will utilize the existing hub infrastructure in the KG D6 block.
“Growing India’s own production of cleaner-burning gas to meet a significant portion of its energy demand, these three new KG D6 projects will support the country’s drive to shape and improve its future energy mix,” BP Chief Executive Bernard Looney said.
The R Cluster field is expected to reach plateau gas production of about 12.9 million standard cubic meters per day (MMscm/D) in 2021. Peak gas production from the three fields should be 30 MMscm/D (1 Bcf/D) by 2023, about 25% of India’s domestic production, and will help reduce the country’s dependence on imported gas.
RIL is the operator of KG D6 with a 66.67% interest; BP holds a 33.33% participating interest.