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Energean Oil & Gas has received the green light from Greek authorities for the Kataloko field development plans (FDP) offshore Western Greece.

Map of Katakolo, from Energean.

Katakolo marks the third oil and gas field to be developed by Energean in Greece, and the first ever hydrocarbon production program in the west of the country.

Energean’s US$50 million development plan is targeting the 11 MMboe of recoverable oil that was discovered in the early 1980s by the state owned Public Petroleum Corp., which has remained undeveloped for decades.

Katakolo will be developed alongside its two other current development projects, the Prinos oil field, which is part of the Prinos Concession offshore North East Greece, and the 2.4 Tcf (2C) Karish and Tanin gas fields, offshore Israel, that also received FDP approval by the Israeli government in August 2017.

Energean will now move to begin the environmental and social impact assessment for Katakolo, which will be submitted for approval next year. Upon approval, the company says it intends to take a final investment decision (FID) on the project and drill the first wells in 2019, with first oil expected in 2020.

“Energean is now unlocking the value of this very important project for the country as well as revealing the potential for wider exploration of the East Adriatic region,” says Energean CEO Mathios Rigas. “Developing Katakolo is consistent with our strategy to maintain a balanced portfolio of producing and development assets, coupled with low-risk, high-impact exploration potential in the Eastern Mediterranean. We are adding further value for our shareholders through converting a discovered but stranded resource into a valuable commercial project.”

In November 2016, Energean secured the 25-year exploitation concession, which involves the development of the field through extended reach wells from an onshore location in the area.

Energean holds a 100% working interest and is the operator of the block.

Read more:

Karish, Tanin Israeli FPSO plan approved

Total JV, Energean get Greek go ahead

Energean submits Karish and Tanin FDP

Energean moves to develop Katakolon, off Greece

Friday, 08 September 2017 07:56

Hyperdynamics fails at Fatala-1

Hyperdynamics failed to encounter hydrocarbons at its Fatala-1 well offshore the Republic of Guinea in Northwest Africa, in what the company thought was to be a “potential world-class hydrocarbon discovery.”

Map from Hyperdynamics.

Fatala-1 was drilled in 2897m of water and reached a total depth of 5117m below sea level.

According to Hyperdynamics, the well encountered a 75m thick Cenomanian sedimentary channel sequence, but it contained predominantly siltstone and clays with no hydrocarbon shows. The well will be plugged and abandoned.

"We are very disappointed at the results of Fatala-1, considering the extremely promising geophysical data on the prospect," says Ray Leonard, Hyperdynamics' president and CEO.

"Hyperdynamics and our 50% partner in the well, Sapetro, currently hold rights to the Guinea concession through 21 September 2017.  In the very near future, we will be studying the results of the well and evaluating any future options we may have for further activity in Guinea. Fatala-1 was the deepest-water well ever drilled offshore Africa, and I'm pleased to say that it was drilled safely and within expected budget," says Leonard.

The duo began drilling well in May, and received a two-year appraisal period extension from the government in July.

Read more:

Hyperdynamics nears final Fatala-1 stage

Hyperdynamics gets Fatala extension

Hyperdynamics starts drilling operations at Fatala

Thursday, 07 September 2017 11:15

Video: Aibel completes Sverdrup assembly

Aibel lifted the final three modules into place for the Johan Sverdrup drilling platform earlier this week. The platform arrived in Haugesund on 5 September, where the facility will remain for hook-up and preparation work, until it is handed over to Statoil in mid-2018. 

The Johan Sverdrup topsides. Images from Øyvind Sætre/Aibel.

The assembly of the three platform modules in Klosterfjorden is one of the largest inshore marine operations in Norwegian history, says Aibel.

According to the company, the main activities of the operation have been to connect the three modules that constitute the drilling platform for the Johan Sverdrup field. 

The first lift was carried out early Sunday (3 September) morning. The crane vessel Thialf lifted the 10,250-tonne heavy main support frame (MSF), built at Aibel’s yard in Thailand, on board the integration barge. 

The following day, the 8000-tonne drilling support module (DSM) was lifted into place on top of the MSF. The lift of the drilling equipment set (DES) from Aibel’s partner Nymo in Grimstad concluded the lifting activities and left one joined platform, which including the grillage is 147m tall, weighing some 22,000-tonne.

“Through two and a half years, our own skilled team has had close collaboration with Statoil, Heerema and other involved parties to plan the operation minute by minute. That effort is now paying off in form of a safe and successful execution in accordance with our plans,” says Stig Jessen, Aibel project director for the Johan Sverdrup drilling platform.

The Johan Sverdrup platform arrived Aibel’s yard in Haugesund on 5 September. 


“Here, it will be moored in autumn and winter, while all installations will be completed, and equipment and systems will be tested and verified, says Aibel. “In early summer 2018, the largest platform deck ever built by Aibel will be handed over to Statoil and head for the field in the North Sea.” 

Johan Sverdrup’s Phase 1 is on track for first oil in late 2019, with an estimated production capacity of 440,000 boe/d. 

Phase 2 will add another processing platform to the field centre which is estimated to increase the processing capacity for the full field to 660,000 b/d. Phase 2 is scheduled to start production in 2022.

Earlier this week partners Aker BP and Lundin said gross capital expenditure was reduced to US$11.8 billion (NOK 92 billion), representing a savings of 25% from the original estimate. 

Aibel was awarded the contract for hook-up of the drilling platform at the Johan Sverdrup field in summer 2018. The hook-up will involve up to 600 employees in rotation until the summer of 2019.

Statoil is the operator of the Johan Sverdrup project with 40.0267% stake. Partners include Lundin Norway (22.6%), Maersk Oil (8.44%), Petoro (17.36%), and Aker BP (11.5733%).

Read more:

Further Johan Sverdrup costs shed

Video: Sverdrup coming into focus

A monster facility

Johan Sverdrup Phase 2 to go ahead

Thursday, 07 September 2017 09:13

LLOG moves on Buckskin development

LLOG Exploration Co. is moving forward to develop its Buckskin project in the deepwater Gulf of Mexico, signing a deal with Seadrill for the West Neptune to begin work later this year. 

West Neptune. Image from Seadrill.

Buckskin is in 6800ft water depth in Keathley Canyon, and extends over six blocks: 785, 828, 829, 830, 871 and 872. The field is estimated to hold nearly 5 billion bbl. 

“Buckskin is a unique opportunity for LLOG,” says Scott Gutterman, LLOG president and CEO.  

Work is scheduled to begin in Q4 2017 with Seadrill's West Neptune drilling rig, which was recently contracted to perform the initial Buckskin work that will include drilling and completing two wells.  

LLOG revealed that the company also ordered several long-lead items for the topsides and is well positioned to achieve first production at Buckskin in 2H 2019. 

“We have also ordered a number of key subsea equipment items from TechnipFMC for the Buckskin Project,” says Gutterman.

The Buckskin project will use equipment rated to 15,000psi and will utilize dual 8in flowlines with riser base gas lift.

Buckskin has been delineated by multiple prior wells and will be a 6mi subsea tieback to the Anadarko-operated Lucius Spar.

The Keathley Canyon 872 #1 discovery well at Buckskin was drilled by Repsol in 2009 to a depth of 29,404ft and encountered some 400ft of net pay in the Upper and Lower Wilcox formations.  Three subsequent appraisal wells drilled in Keathley Canyon 785 and 829 encountered an average of 375ft of high quality oil pay in the Upper Wilcox.  

In January 2016, US supermajor Chevron stepped away from Buckskin, axing the project to focus on its onshore Permian projects. 

LLOG Exploration Offshore is the operator of Buckskin with 31.3% working interest. Partners include Repsol (22.5%), Samson Offshore (22.5%), Beacon Offshore Energy Buckskin (18.7%), and Navitas Buckskin (5%).

Read more:

GoM operators set sights on tiebacks