The Laggan-Tormore gas project in the UK Atlantic Frontier west of Shetland involved building the UK's first gas infrastructure in the region at a cost of £3.5 billion, 18 months late. The project comprised two gas fields, Laggan and Tormore, tied back via subsea pipelines over 140km to an onshore gas processing plant in Shetland. Total brought the project online in late 2015 and it is expected to produce up to 90,000 barrels of oil equivalent per day, supplying much needed domestic gas to the UK. The project signposts what is possible through major investment and cooperation between industry and government to develop remote gas resources.
The document provides an overview of shale activity in several regions around the world. It summarizes shale prospects and challenges in Europe, Australia, Latin America, Africa, China, and key shale basins in Russia, Australia, Argentina, Colombia, Mexico, and Tunisia. Operators active in each region are outlined with well counts, acreage positions, estimated recoverable resources, and initial production rates where available. Challenges include geological complexity, lack of infrastructure and water, and security issues impeding development.
Exploration history of Oil and Gas in GhanaElorm Obenechi
This is a document that Oil and Gas students will find useful. it talks in brief about Oil and Gas exploration in Ghana and current state (as at 2008).
It is a good read.
Open-hole sand-control completions using expandable sand screens (ESS) offer advantages over traditional cased-hole completions including improved production rates and lower installation costs. The documents discusses several case studies where formate brines and ESS were used together, setting world records for longest, hottest, and deepest ESS installations. This included projects by Shell in the Brigantine field in the UK North Sea and by Saudi Aramco in the K-field in Saudi Arabia, improving well economics in both cases.
This document discusses stormwater management approaches for oil and gas well pads throughout various phases of development. It addresses requirements for erosion and sediment control during construction (ESCGP), stabilized sites during extraction, interim restoration post-drilling with post-construction BMPs, final restoration after extraction, and long-term site management. The key considerations are controlling runoff rates and volumes during construction and restoration through temporary and permanent BMPs, while meeting regulatory obligations at different stages.
The document discusses subsea processing technologies and their role in the subsea economy. It notes that subsea processing, including technologies like subsea compression, separation, and boosting, are improving production efficiencies and reserves recovery from oil and gas fields. These technologies also allow functions to be moved underwater, reducing complexity on offshore platforms. The UK North Sea provides opportunities for these emerging subsea technologies as many fields there are maturing. Subsea processing offers cost advantages after initial investment and can help develop smaller, marginal fields by improving recovery and using existing infrastructure. The East of England region has potential to supply these subsea technologies to North Sea fields but currently lacks a significant competency in subsea processing.
2575150, Significant Production Improvement of UltraLow Permeability Granitic...Mostafa Kortam
The document summarizes the significant production improvement of an ultra-low permeability granitic reservoir in Egypt utilizing channel fracturing. Key points:
1) The target formation has very low natural fracture permeability of 0.1-0.5 md, requiring channel fracturing to access oil.
2) Well SID-18 encountered an unconventional granitic formation with challenging logging responses. Analysis found the lithology consists of granite, microgranite, and metagranite fragments.
3) Testing found the formation has an ultra-low permeability. Channel fracturing was utilized to successfully commercialize this challenging asset.
Lomiko Metals significantly expands its Quatre Milles graphite property in Quebec by acquiring an additional 2,180 hectare claim. The expanded property now covers 3,780 hectares and hosts graphite-bearing structures. To earn 100% interest, Lomiko must pay $3,000 and issue 1.8 million shares, subject to regulatory approval. Historical drilling on the original property intersected high-grade graphite, including 8.07% over 28.6 meters. The property is near infrastructure in an established graphite region of Quebec.
Samuel Oben Djan,Lead Geoscientist at GNPC - Neoproterozoic plays and hydroca...Global Business Events
This document discusses the emerging potential for hydrocarbons in Ghana's inland Voltaian Basin. It provides context on global Neoproterozoic hydrocarbon distributions and prospects. While exploration has occurred in the Voltaian Basin since the 1920s, data is limited. The basin is large at over 100,000 sq km with sediment thickness over 6,000m. Shows of oil and gas have been found. Upcoming "Phase I" work includes field studies, satellite imagery analysis, and slim hole drilling to better understand the basin's petroleum system before "Phase II" involving investors.
The document provides an overview of shale activity in several regions around the world. It summarizes shale prospects and challenges in Europe, Australia, Latin America, Africa, China, and key shale basins in Russia, Australia, Argentina, Colombia, Mexico, and Tunisia. Operators active in each region are outlined with well counts, acreage positions, estimated recoverable resources, and initial production rates where available. Challenges include geological complexity, lack of infrastructure and water, and security issues impeding development.
Exploration history of Oil and Gas in GhanaElorm Obenechi
This is a document that Oil and Gas students will find useful. it talks in brief about Oil and Gas exploration in Ghana and current state (as at 2008).
It is a good read.
Open-hole sand-control completions using expandable sand screens (ESS) offer advantages over traditional cased-hole completions including improved production rates and lower installation costs. The documents discusses several case studies where formate brines and ESS were used together, setting world records for longest, hottest, and deepest ESS installations. This included projects by Shell in the Brigantine field in the UK North Sea and by Saudi Aramco in the K-field in Saudi Arabia, improving well economics in both cases.
This document discusses stormwater management approaches for oil and gas well pads throughout various phases of development. It addresses requirements for erosion and sediment control during construction (ESCGP), stabilized sites during extraction, interim restoration post-drilling with post-construction BMPs, final restoration after extraction, and long-term site management. The key considerations are controlling runoff rates and volumes during construction and restoration through temporary and permanent BMPs, while meeting regulatory obligations at different stages.
The document discusses subsea processing technologies and their role in the subsea economy. It notes that subsea processing, including technologies like subsea compression, separation, and boosting, are improving production efficiencies and reserves recovery from oil and gas fields. These technologies also allow functions to be moved underwater, reducing complexity on offshore platforms. The UK North Sea provides opportunities for these emerging subsea technologies as many fields there are maturing. Subsea processing offers cost advantages after initial investment and can help develop smaller, marginal fields by improving recovery and using existing infrastructure. The East of England region has potential to supply these subsea technologies to North Sea fields but currently lacks a significant competency in subsea processing.
2575150, Significant Production Improvement of UltraLow Permeability Granitic...Mostafa Kortam
The document summarizes the significant production improvement of an ultra-low permeability granitic reservoir in Egypt utilizing channel fracturing. Key points:
1) The target formation has very low natural fracture permeability of 0.1-0.5 md, requiring channel fracturing to access oil.
2) Well SID-18 encountered an unconventional granitic formation with challenging logging responses. Analysis found the lithology consists of granite, microgranite, and metagranite fragments.
3) Testing found the formation has an ultra-low permeability. Channel fracturing was utilized to successfully commercialize this challenging asset.
Lomiko Metals significantly expands its Quatre Milles graphite property in Quebec by acquiring an additional 2,180 hectare claim. The expanded property now covers 3,780 hectares and hosts graphite-bearing structures. To earn 100% interest, Lomiko must pay $3,000 and issue 1.8 million shares, subject to regulatory approval. Historical drilling on the original property intersected high-grade graphite, including 8.07% over 28.6 meters. The property is near infrastructure in an established graphite region of Quebec.
Samuel Oben Djan,Lead Geoscientist at GNPC - Neoproterozoic plays and hydroca...Global Business Events
This document discusses the emerging potential for hydrocarbons in Ghana's inland Voltaian Basin. It provides context on global Neoproterozoic hydrocarbon distributions and prospects. While exploration has occurred in the Voltaian Basin since the 1920s, data is limited. The basin is large at over 100,000 sq km with sediment thickness over 6,000m. Shows of oil and gas have been found. Upcoming "Phase I" work includes field studies, satellite imagery analysis, and slim hole drilling to better understand the basin's petroleum system before "Phase II" involving investors.
Champion Iron Mines is developing an iron ore mine in the Labrador Trough region of Canada. Its flagship project is the Consolidated Fire Lake North Project, which has over 5 billion tonnes of mineral resources. A pre-feasibility study for the project outlined an average annual production rate of 9.3 million tonnes of iron concentrate over 20 years. The study found an after-tax IRR of 30.9% and NPV of $3.3 billion, with a 3.4 year payback period. Champion Iron Mines aims to take advantage of existing rail, power and port infrastructure in the established Fermont Iron Ore District.
1) The document discusses conditioning an old vertical well drilled in 1974 in Argentina to stimulate and test productivity from the Vaca Muerta shale formation.
2) A pilot program was conducted on three wells, applying coiled tubing assisted pinpoint completions to independently stimulate small intervals, with 12 stages used over 130m.
3) The pilot was successful, with the wells producing oil naturally. It demonstrated the viability of the completion technique for stimulating older vertical wells in the Vaca Muerta shale.
The document summarizes BP's attempts to control the 2010 Deepwater Horizon oil spill in the Gulf of Mexico. It describes how the oil rig exploded, sinking and rupturing the pipe connected to the oil well. BP attempted multiple techniques to stop the flow of oil including containment domes, insertion tubes, and mud injections, all of which failed. Their most effective method was installing a cap over the blowout preventer, though relief wells were still needed to permanently plug the well.
The document discusses various aspects of oil and gas exploration and production. It begins by noting the economic impact of the oil and gas industry in Alberta, with an employment multiplier of 3.57. It then covers topics like seismic data acquisition using vibroseis trucks and recording trucks, well drilling using rigs, casing, cementing, completions using perforating guns and fracturing, production using pumpjacks and transportation via pipelines, and finally abandonment and site reclamation. The document provides an overview of the technical processes and equipment required to find, drill, produce, and abandon oil and gas wells.
This document summarizes the results of using coiled tubing and a true fluidic oscillator tool to stimulate 20 low production wells in the San Jorge Gulf area of Argentina. Deposits of paraffin, asphaltene, and calcium carbonate were causing damage to the wells. The fluidic oscillator tool generated pressure waves of 300-600 Hz to weaken and remove near-wellbore damage. Treatments of solvent followed by acid were pumped selectively into zones. The approach achieved production increases in oil rates of 30-365% and total fluid rates in 75% of wells. It provides a more cost-effective alternative to conventional well interventions.
This document provides an overview of the Malampaya Deep Water Gas to Power Project in the Philippines. The key points are:
- The project developed an offshore natural gas field discovered in 1989 located 500 km from the nearest market.
- A subsea production system was developed with 5 wells tied back via flowlines to a shallow water platform for gas processing. The gas is then transported via a 504 km pipeline to an onshore gas plant.
- The project successfully delivered gas on schedule in October 2001 to fuel three new gas-fired power plants totaling 3,000 MW, providing much needed electricity to the Philippines.
- Developing this remote deepwater gas field and creating a new gas market required
A team at PDVSA assembled to develop multilateral well technology in Venezuela. They screened reservoirs to identify candidates where multilateral wells could increase production and economics. A key focus was incorporating real-time downhole sensor data into reservoir models to continuously update and improve characterization. This allows technical and economic decisions to be readily made regarding massive implementation of multilateral wells in Venezuela across a wide range of reservoir types.
Dhi uk 2015 - marine - a new approach to modelling long-term shoreline evolut...Stephen Flood
This document discusses a new shoreline evolution model in MIKE 21 FM that uses a constrained morphological approach. It provides conceptual descriptions and examples of applications of the model. The model computes waves, currents and sediment transport on an area mesh and divides the nearshore area into strips to calculate shoreline movement. It offers flexibility with a curved baseline and ability to model complex bathymetry and hydrodynamics over long time scales. Examples shown include offshore breakwaters, ship wrecks, groyne fields, spits, and mega-nourishments. The document describes model inputs, solution techniques, outputs, and methods for speeding up simulations.
This document provides an overview of existing, confirmed, and proposed floating storage and regasification unit (FSRU) projects worldwide as of May 2015. It lists over 100 projects across various regions including North America, South America, Europe, Africa, the Middle East, Asia, and the Indian subcontinent. For each project, it provides brief details on the FSRU vessel, owner/operator, charterer, capacity, and timeframe. The majority of existing projects involve vessels owned by Excelerate Energy, Golar LNG, and Höegh LNG serving as FSRUs.
This document provides information on Farrans, a UK-based building and civil engineering contractor. It summarizes some of Farrans' marine portfolio projects, including the construction of a new deep water berth and quay wall at Belfast Harbour, widening of the Seaforth Passage in Liverpool, repairs to a cooling water outfall structure in Heysham, construction of a new harbour wall in Granton, redevelopment of berthing areas and construction of a new quay wall at Montrose Deep Water Berth, construction of Pointhouse Quay in Glasgow, and renewal of Berth 6 in Montrose.
A draft version of PA's Oil & Gas Drilling rules known as Chapter 78 and 78a, issued by the PA Dept. of Environmental Protection on August 12, 2015. Two different committees will consider this major revision to drilling rules. The newly revised rules are expected to be adopted later this year.
The document discusses the Sakhalin II Phase 2 Project, which involves further developing oil and gas resources on Sakhalin Island, Russia. Phase 2 will include building new offshore platforms at the Lunskoye and Piltun-Astokh fields, constructing a 1,870 km pipeline network, and building an LNG plant and oil export terminal. The project aims to produce up to 150,000 barrels of oil per day and 9.6 million tons per year of LNG for export to markets in Asia Pacific. Significant engineering challenges include the harsh environment of Sakhalin Island and coordination of partners from around the world.
Reconstruction Of Veterans Lane Revised Mayhewmayhew50
This document discusses the reconstruction of Veterans Lane and its impact on the adjacent floodplain. The roadway frequently flooded during storms and needed to be raised. To mitigate increased flooding from raising the road, five large culverts were installed under the road and the far bank was excavated to recreate a wetland area for flood storage. Hydraulic modeling was conducted and showed the changes would actually lower upstream flood levels during storms. The reconstruction project allowed a new housing development to move forward while improving flood management.
This document discusses floating storage and regasification units (FSRUs) as an alternative to onshore LNG terminals. FSRUs offer lower upfront costs, faster development timelines, and flexibility in their location compared to onshore terminals. However, FSRUs also face challenges from meteorological conditions that can disrupt operations and availability. The document outlines the opportunities and risks of FSRUs that developers must consider to determine if an FSRU is the best solution for a given LNG import project.
The presentation proposes building 3 liquefaction trains capable of producing 12 million tonnes of LNG annually on the existing terminal property. This would reduce the volume of natural gas shipped and allow use of the existing infrastructure. Conceptual site plans show locations for the liquefaction equipment, storage tanks, docks, and support facilities that could save costs and construction time. The adjacent site may also be suitable for worker housing and equipment staging.
The document discusses liquefied natural gas (LNG), including what it is, how it is created, and its applications. It describes the LNG value chain and process, from extraction and liquefaction to storage, transport, and regasification. Key LNG solutions and technologies discussed include floating storage and regasification units (FSRUs), LNG storage terminals, gravity-based structures, and ship-to-ship LNG transfers. Advantages of LNG include its efficiency and safety for transport compared to pipelines and its increasing popularity due to advances in production and growing global energy demand.
The UK government approved plans for the world's largest offshore wind farm called the Dogger Bank Creyke Beck project located 80 miles off the Yorkshire coast. The project will consist of up to 400 turbines capable of powering over 2 million homes at an estimated cost of £6-8 billion. It is expected to generate significant economic benefits for the UK while helping the country meet its renewable energy and climate change targets. However, some environmental groups have expressed concerns about the project's potential impacts on local bird populations.
TDW Innovations™ Magazine July - September 2014
Cover Story: A Tale as Big as Texas
With increasing regulation, operators work to overcome the shared challenges of the Eagle Ford Shale play.
New Connections: Europe Reaches for Energy Security
To ensure against fluctuations in geopolitics, many European countries are driving toward more stable energy supplies and the infrastructure needed to support them.
The document provides a PESTEL analysis and SWOT analysis for Bristol Port Company. Key points:
- Government support for a new deep sea container terminal which could create jobs but won't be built until economy recovers.
- Proposal for a tidal barrage was rejected due to negative impacts on Bristol Port.
- Fuel taxes increase transport costs, incentivizing minimizing transport distances which benefits Bristol Port.
- Traffic remains below pre-crisis levels though recovery is expected. Container traffic is growing fastest globally and domestically.
- Population aging may reduce consumer goods demand long-term but population is moving south toward Bristol Port.
Poyry - How can small-scale LNG help grow the European gas market? - Point of...Pöyry
A large new market for natural gas is under rapid development whilst also reducing emissions. LNG is reaching markets previously inaccessible to pipeline gas; as a fuel for transport and for communities remote from the gas grid. A significant development is the use of LNG in marine transport, which currently uses heavy fuel oils.
Champion Iron Mines is developing an iron ore mine in the Labrador Trough region of Canada. Its flagship project is the Consolidated Fire Lake North Project, which has over 5 billion tonnes of mineral resources. A pre-feasibility study for the project outlined an average annual production rate of 9.3 million tonnes of iron concentrate over 20 years. The study found an after-tax IRR of 30.9% and NPV of $3.3 billion, with a 3.4 year payback period. Champion Iron Mines aims to take advantage of existing rail, power and port infrastructure in the established Fermont Iron Ore District.
1) The document discusses conditioning an old vertical well drilled in 1974 in Argentina to stimulate and test productivity from the Vaca Muerta shale formation.
2) A pilot program was conducted on three wells, applying coiled tubing assisted pinpoint completions to independently stimulate small intervals, with 12 stages used over 130m.
3) The pilot was successful, with the wells producing oil naturally. It demonstrated the viability of the completion technique for stimulating older vertical wells in the Vaca Muerta shale.
The document summarizes BP's attempts to control the 2010 Deepwater Horizon oil spill in the Gulf of Mexico. It describes how the oil rig exploded, sinking and rupturing the pipe connected to the oil well. BP attempted multiple techniques to stop the flow of oil including containment domes, insertion tubes, and mud injections, all of which failed. Their most effective method was installing a cap over the blowout preventer, though relief wells were still needed to permanently plug the well.
The document discusses various aspects of oil and gas exploration and production. It begins by noting the economic impact of the oil and gas industry in Alberta, with an employment multiplier of 3.57. It then covers topics like seismic data acquisition using vibroseis trucks and recording trucks, well drilling using rigs, casing, cementing, completions using perforating guns and fracturing, production using pumpjacks and transportation via pipelines, and finally abandonment and site reclamation. The document provides an overview of the technical processes and equipment required to find, drill, produce, and abandon oil and gas wells.
This document summarizes the results of using coiled tubing and a true fluidic oscillator tool to stimulate 20 low production wells in the San Jorge Gulf area of Argentina. Deposits of paraffin, asphaltene, and calcium carbonate were causing damage to the wells. The fluidic oscillator tool generated pressure waves of 300-600 Hz to weaken and remove near-wellbore damage. Treatments of solvent followed by acid were pumped selectively into zones. The approach achieved production increases in oil rates of 30-365% and total fluid rates in 75% of wells. It provides a more cost-effective alternative to conventional well interventions.
This document provides an overview of the Malampaya Deep Water Gas to Power Project in the Philippines. The key points are:
- The project developed an offshore natural gas field discovered in 1989 located 500 km from the nearest market.
- A subsea production system was developed with 5 wells tied back via flowlines to a shallow water platform for gas processing. The gas is then transported via a 504 km pipeline to an onshore gas plant.
- The project successfully delivered gas on schedule in October 2001 to fuel three new gas-fired power plants totaling 3,000 MW, providing much needed electricity to the Philippines.
- Developing this remote deepwater gas field and creating a new gas market required
A team at PDVSA assembled to develop multilateral well technology in Venezuela. They screened reservoirs to identify candidates where multilateral wells could increase production and economics. A key focus was incorporating real-time downhole sensor data into reservoir models to continuously update and improve characterization. This allows technical and economic decisions to be readily made regarding massive implementation of multilateral wells in Venezuela across a wide range of reservoir types.
Dhi uk 2015 - marine - a new approach to modelling long-term shoreline evolut...Stephen Flood
This document discusses a new shoreline evolution model in MIKE 21 FM that uses a constrained morphological approach. It provides conceptual descriptions and examples of applications of the model. The model computes waves, currents and sediment transport on an area mesh and divides the nearshore area into strips to calculate shoreline movement. It offers flexibility with a curved baseline and ability to model complex bathymetry and hydrodynamics over long time scales. Examples shown include offshore breakwaters, ship wrecks, groyne fields, spits, and mega-nourishments. The document describes model inputs, solution techniques, outputs, and methods for speeding up simulations.
This document provides an overview of existing, confirmed, and proposed floating storage and regasification unit (FSRU) projects worldwide as of May 2015. It lists over 100 projects across various regions including North America, South America, Europe, Africa, the Middle East, Asia, and the Indian subcontinent. For each project, it provides brief details on the FSRU vessel, owner/operator, charterer, capacity, and timeframe. The majority of existing projects involve vessels owned by Excelerate Energy, Golar LNG, and Höegh LNG serving as FSRUs.
This document provides information on Farrans, a UK-based building and civil engineering contractor. It summarizes some of Farrans' marine portfolio projects, including the construction of a new deep water berth and quay wall at Belfast Harbour, widening of the Seaforth Passage in Liverpool, repairs to a cooling water outfall structure in Heysham, construction of a new harbour wall in Granton, redevelopment of berthing areas and construction of a new quay wall at Montrose Deep Water Berth, construction of Pointhouse Quay in Glasgow, and renewal of Berth 6 in Montrose.
A draft version of PA's Oil & Gas Drilling rules known as Chapter 78 and 78a, issued by the PA Dept. of Environmental Protection on August 12, 2015. Two different committees will consider this major revision to drilling rules. The newly revised rules are expected to be adopted later this year.
The document discusses the Sakhalin II Phase 2 Project, which involves further developing oil and gas resources on Sakhalin Island, Russia. Phase 2 will include building new offshore platforms at the Lunskoye and Piltun-Astokh fields, constructing a 1,870 km pipeline network, and building an LNG plant and oil export terminal. The project aims to produce up to 150,000 barrels of oil per day and 9.6 million tons per year of LNG for export to markets in Asia Pacific. Significant engineering challenges include the harsh environment of Sakhalin Island and coordination of partners from around the world.
Reconstruction Of Veterans Lane Revised Mayhewmayhew50
This document discusses the reconstruction of Veterans Lane and its impact on the adjacent floodplain. The roadway frequently flooded during storms and needed to be raised. To mitigate increased flooding from raising the road, five large culverts were installed under the road and the far bank was excavated to recreate a wetland area for flood storage. Hydraulic modeling was conducted and showed the changes would actually lower upstream flood levels during storms. The reconstruction project allowed a new housing development to move forward while improving flood management.
This document discusses floating storage and regasification units (FSRUs) as an alternative to onshore LNG terminals. FSRUs offer lower upfront costs, faster development timelines, and flexibility in their location compared to onshore terminals. However, FSRUs also face challenges from meteorological conditions that can disrupt operations and availability. The document outlines the opportunities and risks of FSRUs that developers must consider to determine if an FSRU is the best solution for a given LNG import project.
The presentation proposes building 3 liquefaction trains capable of producing 12 million tonnes of LNG annually on the existing terminal property. This would reduce the volume of natural gas shipped and allow use of the existing infrastructure. Conceptual site plans show locations for the liquefaction equipment, storage tanks, docks, and support facilities that could save costs and construction time. The adjacent site may also be suitable for worker housing and equipment staging.
The document discusses liquefied natural gas (LNG), including what it is, how it is created, and its applications. It describes the LNG value chain and process, from extraction and liquefaction to storage, transport, and regasification. Key LNG solutions and technologies discussed include floating storage and regasification units (FSRUs), LNG storage terminals, gravity-based structures, and ship-to-ship LNG transfers. Advantages of LNG include its efficiency and safety for transport compared to pipelines and its increasing popularity due to advances in production and growing global energy demand.
The UK government approved plans for the world's largest offshore wind farm called the Dogger Bank Creyke Beck project located 80 miles off the Yorkshire coast. The project will consist of up to 400 turbines capable of powering over 2 million homes at an estimated cost of £6-8 billion. It is expected to generate significant economic benefits for the UK while helping the country meet its renewable energy and climate change targets. However, some environmental groups have expressed concerns about the project's potential impacts on local bird populations.
TDW Innovations™ Magazine July - September 2014
Cover Story: A Tale as Big as Texas
With increasing regulation, operators work to overcome the shared challenges of the Eagle Ford Shale play.
New Connections: Europe Reaches for Energy Security
To ensure against fluctuations in geopolitics, many European countries are driving toward more stable energy supplies and the infrastructure needed to support them.
The document provides a PESTEL analysis and SWOT analysis for Bristol Port Company. Key points:
- Government support for a new deep sea container terminal which could create jobs but won't be built until economy recovers.
- Proposal for a tidal barrage was rejected due to negative impacts on Bristol Port.
- Fuel taxes increase transport costs, incentivizing minimizing transport distances which benefits Bristol Port.
- Traffic remains below pre-crisis levels though recovery is expected. Container traffic is growing fastest globally and domestically.
- Population aging may reduce consumer goods demand long-term but population is moving south toward Bristol Port.
Poyry - How can small-scale LNG help grow the European gas market? - Point of...Pöyry
A large new market for natural gas is under rapid development whilst also reducing emissions. LNG is reaching markets previously inaccessible to pipeline gas; as a fuel for transport and for communities remote from the gas grid. A significant development is the use of LNG in marine transport, which currently uses heavy fuel oils.
The document summarizes the installation of an innovative "Capillary Conveyed" gas lift extension system in a well in Vietnam. The existing gas lift system was no longer effective due to declining reservoir pressures. The new system used a 0.75" diameter capillary string to extend the gas lift injection point deeper into the well. After installation, the well resumed production, flowing for 60 days at rates exceeding expectations before being placed on a production cycle. Cumulative production since was 43,000 barrels of oil, with an estimated payback of only 4 days for the installation. The installation demonstrated that the new technology can effectively reinstate production from wells with inefficient gas lift systems.
The document provides an overview of ship repair news from around the world. It discusses the opening of a new dry dock in Malaysia and repairs underway at various shipyards, including repairs on an RFA support vessel in Falmouth and LNG tankers in Spain. It also notes the reopening of a large shipyard on the US West Coast that is conducting emergency and planned repair work on various military and civilian vessels.
1. Petredec opened a new 15,000 metric ton LP Gas terminal in Mauritius in March 2014, representing an investment of $42 million.
2. Three 5,000 tonne LP Gas vessels were transported over 8,200 km by ship from Italy to Mauritius, then offloaded and installed at the terminal site in just eight days through careful planning and coordination.
3. The new terminal aims to transform Mauritius into a regional LP Gas hub and allows Petredec to more efficiently supply Mauritius and other East African markets in the future.
This document discusses meeting future energy needs in the UK through various sources such as shale gas fracturing, wind power, and natural gas. It notes that oil and gas currently make up 85% of UK energy supply and may still fill over 70% of demand through the 2040s. Shale gas is highlighted as a potential new source that could be extracted through hydraulic fracturing, though this process is variable and requires gas-fired plants as backup. Overall the document provides an overview of current and potential future energy sources and infrastructure in the UK.
The document proposes an investment opportunity through a joint venture between Tyumen Oil Group and Green Energy Petroleum to develop liquefied natural gas (LNG) infrastructure in Russia. The joint venture, called Tyumen Oman Oil, aims to attract $4.5 billion in investment to construct an LNG pipeline, terminal, and processing plant with an initial capacity of 10 million tons per year in the Leningrad region of Russia. Further development could increase annual LNG production capacity to 50 million tons, supplying fuel from the North Sea shelf. The project involves purchasing land and obtaining approvals over the next 1-2 years, followed by 3 years of construction.
Nature
July 25, 2013
Vol 499, pg 401
Methane released by melting permafrost will have global impacts that must be better
modelled, say Gail Whiteman, Chris Hope and Peter Wadhams.
Australia has significant natural gas resources and is well positioned to be a major global exporter of LNG. It has proven reserves of 129.9 Tcf and production of 1.5 Tcf annually. By 2020, Australia will have increased its LNG export capacity by 360% through 12 new projects totaling 106.1 MTPA. Australia has a competitive advantage in shipping distances to key Asian markets like Japan and China, which helps offset its relatively high production costs. Major gas basins include Carnarvon, Browse and Bonaparte in Western Australia and the large Canning basin containing up to 1,227 Tcf of potential resource.
Northern Gas Processing Limited (NGPL) was a company that processed natural gas delivered from the North Sea to Teesside, England on behalf of third parties. NGPL's facility was strategically located near the Amco Reception Terminal, which connected it to the Central Area Transmission System pipeline for receiving wet gas. It was also near the Teesside Power Station and the British Gas National Transmission System. The purpose of NGPL's plant was to process the wet gas by removing liquids like propane, butane and condensate, and leaving dry gas that could be sold to end users or through the transmission system. Between 2002-2008, the business and assets of NGPL were restructured and redeveloped,
This summary outlines the design of the OWTISTM ship, which was developed to reduce costs and improve safety for offshore wind turbine installation. The ship has a 1500t crane, large clear deck space, and can operate in deep water and harsh environments. It was designed with a focus on safety, efficiency and cost-effectiveness. Analysis showed this purpose-built floating vessel providing high safety and capacity at low cost per installed unit would better meet the needs of the growing offshore wind industry compared to converted existing vessels.
Liquefied Natural Gas has a number of major advantages as compared to current sources of energy. The major advantages of LNG would be: its ease of transport, its superb quality, its safety, its flexibility of use, and its sustainability.
1. 18 THE PRESS AND JOURNAL
March 2016 EnergyNEWS
West of Shetland project of huge
LAGGAN-TORMORE REVIEW
The £2.5billion Laggan-Tormore pro-
ject on the UK Atlantic Frontier was
given the go-ahead in early 2010 with
the expectation that it should deliver
around 1trillion cu.ft of gas to the UK
market,plussignificantvolumesofcon-
densate for export, starting in 2014.
Like so many major projects, both
targets were missed. Operator Total
brought L-T into production last month
– some 18 month late – and the capex
bill grew to around £3.5billion.
A big chunk of the blame for this lies
with terminal construction contractor
Petrofac which apparently grossly un-
derestimatedjusthowdifficultbuilding
major infrastructure on Shetland is.
That said, this is a hugely strategic
development as it is the UK’s first ever
Atlantic Frontier gas infrastructure and
will play a very important role in do-
mestic production of this backbone,
taken for granted commodity.
L-T also signposts what is possible
when companies and, to some extent
government through fiscal facilitation
withanearly2010taxbreakdesignedto
encourage WoS gas, roll up their sleeves
and get on with it.
But let’s wind back the clock to 1986
when Shell with Britoil drilled a well
200km (125 miles) north-west of Shet-
landin600m(1,968ft)ofwater.Seeking
oil they made a gas-condensate find.
However, the 206/1-2 discovery be-
came for a time one of a number of
gas/liquids finds made on the UK At-
lantic Frontier rendered moribund due
toaperceivedlackofscalecoupledwith
technologychallengesdeemedtoohard
to handle at the time. Indeed, that par-
ticular acreage was to be relinquished.
Nine/ten years later, the licence on
which 206/1-2 was drilled was re-of-
fered via the 16th Oil & Gas Round of
1995 in which Total was awarded the
acreage as it felt there was potential.
The company got on with drilling
threefurtherLagganwells...206/1-3in
1996 to get a better initial feel for what
Shell and Britoil had encountered; then
206/1a-4a and the 206/1a-4aZ sidetrack
of 2004, which was suspended as a pos-
sible future producer, albeit commer-
cial viability remained an issue.
The 206/4AZ well tested at 37.8mil-
lion cu.ft per day of gas. Work contin-
ued on a potentially stand-alone devel-
opmentiftheeconomicscouldbemade
to work and if government assisted to
ease the way financially as the project
would involve a pipeline that others
might use at some time in the future.
Doubts were assuaged with the
205/5a-1 success when Laggan consort
Tormorewasfoundin2007.Totalatlast
had a perhaps viable development.
Driving the project forward during
its early years under Total was the
Frenchgroup’sthenUKNorthSeachief
Michel Contie, who was passionate
about WoS, who wanted to see a com-
mercial gas breakthrough in the sector
and who lobbied government inten-
sively, trying to persuade it to make a
strategic investment in gas transporta-
tion infrastructure.
Contie was unquestionably also an
important catalyst to the eventual cre-
ationoftheWestofShetlandTaskForce
(WoSTF) between the industry and the
UK Government. Its purpose was to
hammer home the strategic value of
WoS as a sub-province of the UK Con-
tinental Shelf.
Prior to Laggan-Tormore coming on-
stream last month, UK Atlantic Fron-
tier gas export infrastructure was lim-
ited to the BP-operated 20-inch West of
Shetland Pipeline System and the East
of Shetland Pipeline System which to-
gether transport associated gas from
Clair and the Schiehallion/Foinaven
fields to BP’s Magnus field East of Shet-
land for enhancing oil recovery.
Given the third-party business di-
mension to the Laggan-Tormore
pipeline, little wonder Contie applied
pressure and eventually the Treasury
got around to listening and acting.
It was in January 2010, that the then
governmentintroducedataxallowance
worth up to £160million per field to
help stimulate investment WoS.
Roland Festor, Total’s head of UK ex-
ploration and production at the time,
said the allowance would be “very im-
portant” for Laggan-Tormore.
So, what of the reservoirs and the de-
velopment plan?
Laggan is a good quality Palaeocene
gas-condensate reservoir and is a com-
bination structural/stratigraphic trap.
Its crest is 3,500m below the sea floor
and it has a 400m gas column.
The areal extent of the reservoir is
42sq.km.Totalgrossreservoirthickness
(T35 sands) is less than 70m (including
two field-wide inter-bedded shales).
The reservoir comprises sand-rich
turbidite lobe facies, with the reservoir
architecture controlled by compensa-
tion and normal faults.
Tormore resembles Laggan in terms
of trapping configuration, depositional
model and reservoir properties. The
main difference is the fluid, with Tor-
more gas condensate being about three
times richer than Laggan. The reservoir
lies at a depth of 5,505m (crest).
The fact that Tormore is richer than
Lagganwasofconsiderableimportance
in terms of commerciality as that “wet-
ness” helped swing the viability pendu-
lum in the right direction.
It is located some 16km south-west of
its neighbour and had for some years
been recognised as a potential gas re-
source by the licence partners.
In parallel to the activities of the
WoSTF talks, the Tormore partners put
together a plan to drill the prospect in
summer 2007 using the Sedco 714 rig.
That well spudded on June 13, 2007,
andtotaldepthwasreachedinlessthan
twomonthsonAugust3.Afterfinallog-
ging a drill-stem test was performed.
Accordingtoapaperpreparedforthe
Society of Petroleum Engineers by To-
tal, the discovery in Tormore of appre-
ciable further quantities of gas conden-
sate close to Laggan brought a welcome
boost to the WoSTF and “put the ball
firmly back in the court for the Laggan-
Tormore partners to push forward with
their plans to open up a new gas export
infrastructure for the region”.
After preliminary studies confirmed
the potential economic value of a com-
binedproject,thepartnershipagreedto
move forward with an aggressive
schedule of development studies aimed
at selecting the optimum development
concept by mid 2008.
Departing from the conventional se-
quence of conceptual studies followed
by pre-project, it was agreed to update
the original standalone Laggan pre-
project to take account of Tormore
while in parallel running an offshore
hub conceptual study.
Three options were considered:
● Onshore hub: a long distance subsea
tie-back of more than 140km to a new
onshore gas processing plant close to
the existing BP-operated terminal at
Sullom Voe;
● Shallow water hub: a subsea tie-back
to a new platform in 150m water depth
on the shelf close to the existing BP-op-
erated Clair platform;
● Deepwater hub: a subsea or dry tree
tie-back to a floating TLP (tension-leg
platform) or deep draft semi-sub-
mersible moored in 600m close to the
sister fields.
According to the SPE paper, the later
inclusion of Tormore did not have a sig-
nificanteffectonthefindingsoftheear-
lier environmental screening studies.
In the event, the decision was made
to develop Laggan-Tormore based on a
subsea package offshore, tied back via
two multiphase flowlines to a shore-
basedprocessingplantlocatedatSullon
Voe in Shetland and which would be
built with spare capacity to enable fu-
ture tie-ins from other projects. Indeed
L-T has set a new UK record for subsea
tie-backs to the beach.
Export from the gas plant at Sullom
Voe would connect to the existing
FUKA line in the northern North Sea,
which in turn feeds into St Fergus ter-
minal for final processing into sales gas
and commercial export.
Condensate would be separated from
the gas during processing at the new
Shetland facility, then stabilised and ex-
ported by tanker from existing BP fa-
cilities at Sullom Voe.
The gas production plant would be
designedtoprocess500millioncu.ftper
daygas,plusassociatedcondensate(de-
sign rate 27,900 barrels per day).
To take account of future third party
gas production the export facilities will
at some point in the future be upgraded
for up to 665million cu.ft per day. The
export line is already sized to take ac-
count of this additional requirement; a
wisedecisionbearinginmindthatTotal
has already initiated developments of
nearby Glenlivet and Edradour.
The key reason behind opting for a
subsea tie-back to the beach with all op-
erations staff being shore-based is
safety. However, it also facilitates access
for third parties to the regional gas
transportationsystem;andasubseatie-
back to shore, with the addition of sub-
sea compression in late field life, will
Operator Total brought Laggan-Tormore into commercial
production last month, writes Jeremy Cresswell as he charts
something of the history of the UK’s first Atlantic Frontier
natural gas production infrastructure
Above: The gas terminal and, below, the MEG treatment area
2. THE PRESS AND JOURNAL
March 2016Energy 19NEWS
strategic importance to Britain
allow maximum recovery of reserves.
An elegant if challenging solution.
There is also the issue of the physical
environment . . . another good reason
why the subsea/onshore approach was
selected. The water current patterns in
the vicinity of the sister fields are com-
plex with various strong non-tidal cur-
rents interacting with relatively weak
tidal flow.
On the surface, the deep water over
the West of Shetland continental slope
is exposed to a large oceanic fetch and
strong winds, particularly from the
west and south-west. These conditions
can generate an extreme wave regime
that is more severe than that experi-
enced in the Northern North Sea. The
area is also affected by long periods of
ocean swells generated from Atlantic
storms.
It was planned that drilling opera-
tions at Laggan-Tormore would be car-
ried out in two phases. To facilitate this,
a six-slot template-manifold was lo-
cated on the seabed at each of the Lag-
gan and Tormore locations.
Under phase one, three new wells
were drilled at Laggan plus re-entry of
one of the existing wells; together with
one new well at Tormore.
Further wells are planned and will be
located optimally following the review
of year one production data.
The well suite is controlled via an
electro-hydraulic umbilical, which in-
cludes cores for the transport and in-
jection of chemicals (scale, corrosion
and wax inhibitor) as well as methanol
for start-up purposes.
Now that L-T is onstream, Total and
assetspartnersDONGandSSEarehop-
ing for peak production rates of at least
90,000 barrels oil equivalent per day.
Output is then expected to decline
graduallyovertimethroughnaturalde-
pletion of the reservoirs. This will to an
extentbecounteredbytheuseofsubsea
compression though this was not a part
of the original development plan.
As for future additions to L-T infras-
tructure, that has already started with
field development plans for the
Edradour/Glenlivet project approved
by government last year. The original
decision to invest in this was taken by
Total in May 2014.
The Edradour field is located on
block 206/4a, in some 300m of water.
The development plan consists of the
conversion of the discovery well into a
productionwellanda16kmproduction
pipeline tied back to the main Laggan-
Tormore flowline.
Edradour is expected to start up in
Q4 2017 and to reach a plateau of 17,000
barrels oil equivalent per day.
Glenlivet is located on block 214/30a,
in 435m of water and will be developed
with two wells using a single four-slot
manifold on the seabed and a 35km
pipeline tied back to the Laggan-Tor-
more production flowline.
FirstgasisexpectedinQ32018andto
plateau at 21,000boe per day.
And thus begins Total’s third and
frontier-busting production hub in UK
waters . . . another source of domestic
gas that should help keep our hydro-
carbons imports bill at bay.
The long-term hope is that further
gas discoveries will be tied in and that
the infrastructure is extended.
Total E&P UK operates Laggan-Tor-
more with a 60% interest alongside
partners DONG E&P (UK) Limited
(20%) and SSE E&P UK Limited
(20%).
The mighty task of 2,700 workers to pioneer first UK Atlantic Frontier gas infrastructure
Simon Hare –
West of Shetland
asset manager
The industry had been looking at how
to extract gas from West of Shetland for
decades. When I first joined Total in
the mid-1990s, it was involved with a
group of companies on what was called
the Aurora project.
At that time, we were looking at joint
industry strategies to develop both oil
and gas in the region. That was a period
when the industry was doing a lot of
drilling West of Shetland.
History obviously speaks for itself in
that, at that time, there were no major
gas discoveries made. The Aurora
initiative didn’t go anywhere.
Two decades on and with Total
involved, we got to a point where,
thanks to the discovery of Laggan way
back and Tormore more recently,
there was sufficient critical mass to
justify a commercial development.
So what is the significance? It’s
thanks to this development that we
now have a terminal and a gas
pipeline that runs right out to the
heart of the West of Shetland area;
and that provides a backbone for
Total’s own developments – current
and future – and clearly too, future
developments by other operators.
Margaret Muir –
Laggan-Tormore
services manager
Prior to becoming involved with
Laggan-Tormore, I had been in the
company for more than 15 years. With
this project, Total needed someone to
join that team and set up project
services . . . cost control, HR,
planning, contracts, logistics and IS
. . . the systems side.
We’re the ones who have kept
everything running smoothly and at
the right time; back office stuff. The
big challenge of my role was the sheer
number of people involved . . . around
2,700 at peak.
We had a team of 250 people
representing just Total on the project.
And the contractors . . . like Subsea 7
and Petrofac, which had their own
workforces, had to liaise with us. We
had an HR team dedicated to making
sure that the relationships between
Total and the different contractors
worked smoothly.
This included making sure the
workforce travelled to and from
Shetland safely, that they had all the
right accommodation; things like that.
There’s been a lot of work going on
behind the scenes to make sure all of
this worked smoothly.
When you bring 2,700 people into a
small community like Shetland it was
inevitable that there would be issues.
But we had a really good relationship
with Petrofac, which was responsible
for seeing that any actions agreed
were seen through.
David Hainsworth –
UK operations manager
Personally, I was involved early on
in the project to help define the
operating philosophy, once it was
decided that it was going to be a
subsea development with a long
tieback.
Norwegian projects Ormen Lange
and Snohvit with their subsea
infrastructure and onshore facilities
helped Total towards its decision to
opt for a long subsea tieback direct
to infrastructure onshore.
Clearly, if the platform route had
been taken, there would potentially
have been the opportunity to lower
wellhead pressures in late field life.
Equally, we now know from other
developments that there are other
potential ways of doing this, such as
subsea compression, that could
come along in the future to achieve
the same thing.
Also, by going subsea, most of the
year we don’t need to be offshore
and that delivers safety benefits. It’s
an elegant solution that works well
with gas.
As for having an operations
centre onshore, that brings
significant safety advantages and we
have space. We can easily have big
equipment like gas compression
with waste head recovery systems.
These are hard to fit aboard
platforms; much easier onshore
where we have much more space.
The first challenge we have now
that we’re operational is to keep the
plant full. We have really good
infrastructure; we have a very large
plant with a lot of capacity that will
give us flexibility in the future so
similar wet gas developments can
be tied into the system at very little
cost.
That’s why Edradour-Glenlivet
can be made economic.
Aerial view of Laggan-Tormore gas terminal