Energean is the Operator in the Prinos licence, Northern Greece, where has a 100 per cent working interest. Prinos, Prinos North and Epsilon are currently the only producing fields in Greece and have produced app. 130 mmboe so far.
Prinos, Prinos North and Epsilon oil fields are located in the Gulf of Kavala, 18 km south of the mainland of Northern Greece, in water depth of 30 to 38 metres.
Energean has agreed with Greece's PPC to purchase for the Prinos asset electricity that is generated 100% by renewables. This agreement has driven a 100% reduction in the asset’s Scope 2 carbon emissions and an approximate 45% reduction of Scope 1 & 2.
Since 2009, Energean has successfully completed three wells and seventeen interventions in the fields of the Prinos Concession with its privately owned drilling rig "Energean Force" and the four jack ups it mobilised in the Gulf of Kavala.
The Company managed to increase 2P reserves to 36 mmboe from just 2 mmboe in 2007. Prinos also has 64 mmboe 2C resources.
In May 2021, Energean made FID on the revised Epsilon shallow-water tie-back development.
Epsilon Phase 1 development includes construction of the Lamda platform and completion of the three pre-drilled production wells. Production is expected to commence in 1H 2024.
PRINOS ENVIRONMENTAL AND SOCIAL IMPACT ASSESSMENT - MAIN ASSETS
ESIA Full Main Report
ESIA Cover page and Table of Contents
ESIA Chapter 01 Introduction
ESIA Chapter 02 Executive Summary
ESIA Chapter 03 Summary Project Description
ESIA Chapter 04 Objective & Rationale
ESIA Chapter 05 Project Compatibility
ESIA Chapter 06 Project Description
ESIA Chapter 07 Alternative Solutions
ESIA Chapter 08 Environmental and Social Baseline
ESIA Chapter 09 Environmental and Social Scoping
ESIA Chapter 10 Emergencies and Risks
ESIA Chapter 11 Impact Assessment
ESIA Chapter 12 Mitigation and Management Measures
ESIA Chapter 13 Environmental & Social Management and Monitoring Plan
PRINOS ENVIRONMENTAL AND SOCIAL IMPACT ASSESSMENT - ANNEXES
ESIA Annexes Cover Page
ESIA Annex 02 Maps and drawings
ESIA Annex 03 Geophysics survey
ESIA Annex 04 Specific Ecological Study
ESIA Annex 05 Study of the benthic communities
ESIA Annex 6.1 PAH Report
ESIA Annex 6.2 Chemical Analysis Pollution Assessment
ESIA Annex 07 Oil Spill Modelling Report
ESIA Annex 08 Chemical Use Plan
ESIA Annex 09 Waste Management Plan
ESIA Annex 10 Noise Measurements
ESIA Annex 11 Stakeholder Engagement Plan
EISA Annex 12 Chance Finds Procedure for Cultural Heritage
ESIA Annex 13 Contingency Plan
ESIA Annex 14 HSE Plan
ESIA Annex 16 Construction Management Plan
ESIA Annex 17 Biodiversity Wildlife Management Plan
ESIA Annex 18 Pollution Management Plan
PRINOS ENVIRONMENTAL AND SOCIAL IMPACT ASSESSMENT - OTHER DOCUMENTS
Following exploration of the Prinos Basin in the 1970s, the Prinos Field was discovered in 1974 through the drilling of Prinos-1, the first exploration well drilled in the area. It was developed during the late 1970s and brought into production in 1981.
The initial development of the field took place from 1979 until 1981, following the drilling of the delineation wells which confirmed the extent of the Prinos reservoir,. Facilities were installed offshore and onshore to allow 30,000 bopd to be produced along with associated gas. Two drilling jackets were installed above the Prinos Field and bridge linked to an unmanned offshore processing platform. Via a pipeline, these offshore facilities were linked by pipeline to the shore, where a complex gas and oil processing plant was constructed along with oil storage tanks (500,000 bbl capacity) and offshore loading terminal.
Crude oil production commenced in early 1981, at initial rates of 8,000 to 10,000 bopd, with production peaking at more than 27,000 bopd in 1985. Prinos 2P reserves were initially estimated at 60 million oil bbls, but the field has already produced more than 110 million bbls since 1981.
The Prinos North structure was initially identified as a potential exploration opportunity in 1976, when the Prinos-4 (P-4) delineation well encountered small quantities of oil to the north of the Prinos Oil Field.
Prinos North was appraised and developed as a satellite field to Prinos by an extended reach horizontal well, PNA-H1, in 1996. The following year, PNA-H1 was brought in production and produced until 2004 at an initial rate of 3,000 bbls/d with an interruption during the period 1998-1999, when a decline set in due to water breakthrough.
An extended reach well, PNA-H3, was successfully drilled by Energean in 2009, through a challenging operation due to the geological complexity of the target reservoir. The well reached a total depth of 4,370 metres, with a 358metre horizontal section into the reservoir.
Exploration activity in the Epsilon Field area began in the 1990s, when the anticlinic Epsilon structure was identified by the interpretation of 2D seismic data. The area remained a low priority, and was only partially covered by the 1993 3D seismic cube. The 3D seismic survey conducted in 1997, however, covered the whole area and made it possible to map the structure, and consequently upgrade Epsilon as a high priority exploration target.
The field was discovered in 2000 when Well E-1 tested sour crude oil with an API gravity of 36 degrees in reservoirs belonging to the Prinos Group at a depth of about 2,800 metres TVDSS. The well was side-tracked a year later to a location some 500 metere to the south-east, confirming the reservoir presence and tested oil.
Energean drilled an extended reach multi-lateral well, EA-H1, which was completed in January 2010 and produced over 0.3 mmbbls of oil over a 12-month period. The length of the well reached 5,297 metres, with more than 450 metres horizontal section of each leg, making it the longest well in the Mediterranean to date.
The 2015 Seismic Survey
Energean conducted a 340 km2 broadband 3D seismic survey over the Prinos Oil Field and its surrounding licences in the Gulf of Kavala during the summer of 2015. The survey al;so included a complex undershooting operation in the vincinity of the Prinos offshore platform.
The 3D seismic survey acquired in 2015 was processed by Down Under Geosolutions (DUG) in 2016 using the PSTM processing workflow. The interpretation of the seismic data was critical in updating the Prinos field static model and the identification of remaining oil.
Consequently the optimal placement of infill wells resulted in the improved depletion of the Prinos Field. The 3D seismic volume was important in refining the placement of the PNA-H4 Prinos North well.
The Epsilon filed static model was also updated in order to assist in the design of the producing wells and the optimum positioning of the Epsilon offshore facilities. The successful well depth prognosis for the vertical wells and the horizontal EA-H3 wells showed the value of the better quality 3D velocity model and the increased resolution of the encountered seismic reflectors resulting from the PSDM re-processing.
In July 2018, Energean discovered oil pay intervals in the deeper Kazaviti and D horizons in the PA-32 well. Based on well logs, both reservoir units were predicted to be of low permeability and discrete well tests were unable to establish a flow to surface. Oil was subsequently seen and sampled at the PA-32 wellhead immediately prior to perforating operations on the shallower B-reservoir.