Inspection of Clad and Plain Carbon Steel Girth Welds on Offshore Caisson Risers Using Semi-Mechanised Ultrasonic Testing (SMUT)

2008 ◽  
Author(s):  
Robert J. Conder ◽  
Ryan McPherson ◽  
Ton Kooren ◽  
Allan Parlane
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Plain Carbon Steel ◽  
Gas Production ◽  
Carbon Steels ◽  
Inconel 625 ◽  
Inspection System ◽  
Oil And Gas Production ◽  
The North ◽  
Girth Welds

Caisson risers installed through drilling slots are an increasingly common method to add additional riser access to existing oil and gas production platforms. This paper describes the inspection methodology used for two new caisson risers on the Talisman Energy owned Tartan platform in the North Sea. The methodology for qualification of the inspection system for both plain carbon steels and Inconel 625 (UNS N06625) clad carbon steel is described. The offshore performance of the SMUT system is discussed and the time and safety benefits of this system are highlighted.

Development of semi-submersible production vessels and its application to Australian waters

2008 ◽  
Vol 48 (1) ◽  
pp. 241
Author(s):  
Hilde Engelsen ◽  
Henrik Hannus
Keyword(s):  
North Sea ◽  
Environmental Conditions ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
The North ◽  
Hull Design ◽  
Steel Catenary Risers ◽  
Drilling Rigs ◽  
In The Beginning

Semi-submersible platforms have a long history in the North Sea. In the beginning they were used mainly as mobile offshore drilling units, but in the last two decades the permanently moored semi-submersible production vessels have become widely used both as gas processing units and combination oil and gas production vessels. The design of production semi-submersibles evolved from that of drilling rigs, but there have since been significant improvements to the design of the hull and the topside configuration in relation to operational requirements and construction processes. The design methods have also been successfully adapted to areas with different environmental conditions, in combination with steel catenary risers and polyester mooring systems. On recent designs, simplifications of the hull systems are being implemented, which ease operation and enhance the passive safety. Finally, the semi-submersible production vessel’s application to Australian waters is discussed with focus on topside layout, hull design and mooring system design. Environmental conditions offshore northwest Australia are compared to North Sea and Gulf of Mexico conditions, along with vessel class and regulatory requirements.

Experience With Qualification and Use of Stainless Steels in Subsea Pipelines

2004 ◽  
Author(s):  
Per Egil Kvaale ◽  
Tore Ha˚brekke ◽  
Gisle Ro̸rvik
Keyword(s):  
Stainless Steels ◽  
Oil And Gas ◽  
Production Systems ◽  
Gas Production ◽  
Inconel 625 ◽  
Oil And Gas Production ◽  
Internal Corrosion ◽  
Carbon Manganese Steels ◽  
Subsea Pipelines ◽  
Incoloy 825

Use of stainless steels in subsea oil and gas production systems have been common through the development of remote controlled subsea oil and gas production systems. Stainless steels are mainly selected to minimize the corrosion due to unprocessed oil and gas and thereby simplifying the internal corrosion protection challenges. Different materials and principles have been implemented from cladding of Carbon Manganese steels to the use of solid stainless steels. For cladding Incoloy 825 or Inconel 625 is common, while the solid stainless steels have been duplex, superduplex or 13%Cr steels in pipes and pipe fittings. Experience from service has shown that these materials have limits in their use, and it is reported various cases where the stainless steels have failed. The present paper will deal with a few examples of failures and possible reasons for these failures.

scholarly journals Late Cretaceous basin development of the southern Danish Central Graben

1969 ◽  
Vol 20 ◽  
pp. 15-18
Author(s):  
Finn Jakobsen ◽  
Claus Andersen
Keyword(s):  
Late Cretaceous ◽  
Oil And Gas ◽  
Seismic Inversion ◽  
Gas Production ◽  
Structural Development ◽  
Oil Accumulation ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
Basin Development

The Danish oil and gas production mainly comes from fields with chalk reservoirs of Late Cretaceous (Maastrichtian) and early Paleocene (Danian) ages located in the southern part of the Danish Central Graben in the North Sea. The area is mature with respect to exploration with most chalk fields located in structural traps known since the 1970s. However, the discovery by Mærsk Oil and Gas A/S of the large nonstructurally and dynamically trapped oil accumulation of the Halfdan Field in 1999 north-west of the Dan Field (e.g. Albrechtsen et al. 2001) triggered renewed exploration interest. This led to acquisition of new high quality 3-D seismic data that considerably enhanced imaging of different depositional features within the Chalk Group. Parallel to the endeavours by the operator to locate additional non-structural traps in porous chalk, the Geological Survey of Denmark and Greenland took advantage of the new data to unravel basin development by combining 3-D seismic interpretation of a large number of seismic markers, well log correlations and 2-D seismic inversion for prediction of the distribution of porous intervals in the Chalk Group. Part of this study is presented by Abramovitz et al. (in press). In the present paper we focus on aspects of the general structural development during the Late Cretaceous as illustrated by semi-regional time-isochore maps. The Chalk Group has been divided into two seismically mappable units (a Cenomanian–Campanian lower Chalk Unit and a Maastrichtian–Danian upper Chalk Unit) separated by a distinct basin-wide unconformity.

WESTERN AUSTRALIA—A TECHNOLOGY BASE FOR THE OIL AND GAS INDUSTRY

2001 ◽  
Vol 41 (1) ◽  
pp. 777
Author(s):  
B.F Ronalds
Keyword(s):  
Oil And Gas ◽  
Local Environment ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
International Industry ◽  
Analytical Tools

Oil and gas production is characterised by a truly international industry, and yet a unique local environment. Solutions developed elsewhere cannot always be imported directly for Australian use. For this reason alone, a strong local technology base is of value to the Australian oil and gas industry. Other benefits include the ability to provide high quality education and training for people entering, and already in, the industry.A case study is described where the Western Australian technology base is facilitating solutions to a specific challenge faced on the North West Shelf (NWS); namely, that the criteria for reliable development and operation of its offshore infrastructure for oil and gas production are more severe than other petroleum provinces, requiring new analytical tools to be developed.

Practical Experience in Rig Move and Workover Operations in an Amphibious Terrain: A Case Study of Escravos Beach Rig Move and Workover Operations

2016 ◽  
Author(s):  
Joy Eze ◽  
Oluwarotimi Onakomaiya ◽  
Ademola Ogunrinde ◽  
Olusegun Adegboyega ◽  
James Wopara ◽  
...  
Keyword(s):  
Niger Delta ◽  
Joint Venture ◽  
Oil And Gas ◽  
Practical Experience ◽  
Gas Production ◽  
Health Security ◽  
Oil And Gas Production ◽  
The North ◽  
The Government ◽  
Petroleum Development

ABSTRACT The exploration and production of oil and gas mostly occurs in remote locations, so as to minimize human exposure and Health Security Safety and Environment (HSSE) risks. Shell Companies in Nigeria is not any different having operated for over 50 years in Nigeria with the largest footprint of all the international oil and gas companies operating in the country spanning over land, swamp, shallow waters and offshore terrains. Shell Petroleum Development Company, the operator of a joint venture (the SPDC JV) between the government-owned Nigerian National Petroleum Corporation – NNPC (55% share), Shell (30%), Total E&P Nigeria Ltd (10%) and the ENI subsidiary Agip Oil Company Limited (5%) focuses mostly on onshore and shallow water oil and gas production in the Niger Delta with about 60+ producing oil and gas fields and a network of approximately 5,000 kilometers of oil and gas pipelines and flow lines spread across the Niger Delta. Escravos Beach is over 60km from the closest major city, Warri, a major oil and gas zone in the Niger Delta. It is bounded by the Escravos River to the East, Chevron canal to the North and the Atlantic Ocean to the South and is covered with predominantly mangrove forest especially along the creeks and consists of a number of natural and man-made waterways (rivers, creeks and canals). Unlike most other onshore operations, this location can only be accessed via the waterways; thus requiring the rig equipment and every other equipment to be channeled via the waterways and subsequently on land to arrive at the site. The amphibious nature of this operation requires a combination of onshore and swamp requirements with increased HSSE exposure, logistics requirement and cost. This paper aims to highlight the practical experience garnered in the rig move and workover operations of Rig XYZ which operated in the Escravos Beach region.

Velocity Guidelines for Avoiding Erosion-Corrosion Damage in Sweet Production With Sand

1998 ◽  
Vol 120 (1) ◽  
pp. 78-83 ◽  
Author(s):  
J. R. Shadley ◽  
E. F. Rybicki ◽  
S. A. Shirazi ◽  
E. Dayalan
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Corrosion Damage ◽  
Gas Production ◽  
Metal Loss ◽  
Co2 Corrosion ◽  
Oil And Gas Production ◽  
Erosion Corrosion ◽  
Steel Piping ◽  
Loss Rates

CO2 corrosion in carbon steel piping systems can be severe depending on a number of factors including CO2 content, water chemistry, temperature, and percent water cut. For many oil and gas production conditions, corrosion products can form a protective scale on interior surfaces of the piping. In these situations, metal loss rates can reduce to below design allowances. But, if sand is entrained in the flow, sand particles impinging on pipe surfaces can remove the scale or prevent it from forming at localized areas of particle impingement. This process is referred to as “erosion-corrosion” and can lead to high metal loss rates. In some cases, penetration rates can be extremely high due to pitting. This paper combines laboratory test data on erosion-corrosion with an erosion prediction computational model to compute flow velocity limits (“threshold velocities”) for avoiding erosion-corrosion in carbon steel piping. Also discussed is how threshold velocities can be shifted upward by using a corrosion inhibitor.

scholarly journals Corrosion Investigation of Commercially Available Linepipe Steel in CO2 Environment

2018 ◽  
Vol 7 (3.32) ◽  
pp. 15
Author(s):  
Muhammad Haris ◽  
Saeid Kakooei ◽  
Mokhtar Che Ismail
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Corrosion Behaviour ◽  
Complex Problem ◽  
Gas Production ◽  
Co2 Corrosion ◽  
Oil And Gas Production ◽  
The Difference ◽  
Co2 Environment

CO2 corrosion has been the most prevalent form of corrosion and is considered as a complex problem in oil and gas production industries. The CO2 in presence of water causes sweet corrosion that is responsible for failure of pipeline during transportation of Oil and Gas. This work studies the corrosion behaviour of carbon steel specimens in CO2 environment at different temperatures but at constant pressure. The effect of CO2 on Carbon Steel specimens (X65, A106) were studied in simulated solution of 3 wt.% NaCl. The specimens were immersed into the CO2 containing solution for 48 hours and corrosion behaviour was investigated by using electrochemical test like Linear Polarization Resistance and Tafel plot. The results indicate that the temperature has an important effect of corrosion rate of carbon Steel in CO2 environment. Corrosion rate of 1.5-2 mm/yr was reported for both steels at lower temperature while at higher temperature the difference can be observed due to difference in protective nature of steels. Similar Corrosion rate around 1.5 -2 mm/yr was observed at 25°C for both A106 and X65 while at 50°C and 75°C the corrosion rate varies significantly 1.5-3 mm/yr and 3.5-6 mm/yr.  

The Beryl Field, Block 9/13, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 33-42 ◽  
Author(s):  
C. A. Knutson ◽  
I. C. Munro
Keyword(s):  
North Sea ◽  
Middle Jurassic ◽  
Oil And Gas ◽  
Upper Jurassic ◽  
Lower Jurassic ◽  
Gas Production ◽  
Upper Triassic ◽  
Oil Field ◽  
Oil And Gas Production ◽  
The North

AbstractThe Beryl Field, the sixth largest oil field in the UK sector of the North Sea, is located within Block 9/13 in the west-central part of the Viking Graben. The block was awarded in 1971 to a Mobil operated partnership and the 9/13-1 discovery well was drilled in 1972. The Beryl A platform was emplaced in 1975 and the Beryl B platform in 1983. To date, ninety-five wells have been drilled in the field, and drilling activity is anticipated into the mid-1990s.Commercial hydrocarbons occur in sandstone reservoirs ranging in age from Upper Triassic to Upper Jurassic. Structurally, the field consists of a NNE orientated horst in the Beryl A area and westward tilted fault blocks in the Beryl B area. The area is highly faulted and complicated by two major and four minor unconformities. The seal is provided by Upper Jurassic shales and Upper Cretaceous marls.There are three prospective sedimentary sections in the Beryl Field ranked in importance as follows: the Middle Jurassic coastal deltaic sediments, the Upper Triassic to Lower Jurassic continental and marine sediments, and the Upper Jurassic turbidites. The total ultimate recovery of the field is about 800 MMBBL oil and 1.6 TCF gas. As of December 1989, the field has produced nearly 430 MMBBL oil (primarily from the Middle Jurassic Beryl Formation), or about 50% of the ultimate recovery. Gas sales are scheduled to begin in the early 1990s. Oil and gas production is forecast until licence expiration in 2018.The Beryl Fields is located 215 miles northeast of Aberdeen, about 7 miles from the United Kingdom-Norwegian boundary. The field lies within Block 9/13 and covers and area of approximately 12 000 acres in water depths ranging from 350-400 ft. Block 9/13 contains several hydrocarbon-bearing structures, of which the Beryl Fields is the largest (Fig. 1). The field is subdivided into two producing areas: the Beryl Alpha area which includes the initial discovery well, and the Beryl Bravo area located to the north. The estimated of oil originally in place is 1400 MMBBL for Beryl A and 700 MMBBL for Beryl B. The fiel has combined gas in place of 2.8 TCF, consisting primarily of solution gas. Hydrocarbon accumulations occur in six reservoir horizons ranging in age from Upper Triassic to Upper Jurassic. The Middle Jurassic (Bathonian to Callovian) age Beryl Formation is the main reservoir unit and contains 78% of the total ultimate recovery.The field was named after Beryl Solomon, the wife of Charles Solomon, who was president of Mobil Europe in 1972 when the field was discovered. The satellite fields in Block 9/13 (Nevis, Ness and Linnhe) are named after Scottish lochs.

scholarly journals NEW DATA ON PROMISING OIL AND GAS OBJECTS IN THE SANDSTONES OF THE YAMNA SUITE OF THE PALEOCENE IN THE NORTHWEST OF THE SKIBA ZONE OF THE UKRAINIAN CARPATHIANS

2021 ◽  
pp. 90-110
Author(s):  
V.Ye. Shlapinskiy ◽  
H.Ya. Havryshkiv ◽  
Yu.P. Haievska
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Distribution Area ◽  
Total Production ◽  
Reservoir Properties ◽  
Oil And Gas Production ◽  
The North ◽  
Natural Oil ◽  
Porosity And Permeability

More than 6 million tons of the oil have been extracted in the Skybа Zone of the Ukrainian Carpathians. In particular, 4.2 million tons of oil (85.7% of total production) were obtained from the Yamna sandstones of Paleocene, which are characterized by satisfactory physical properties. Most of the areas of fields that exploited them are located in the Boryslav oil and gas production area. Among them are such oil fields as Skhidnytsko-Urytske (more than 3.8 million tons of oil extracted), Violeta, Faustina, MEP, Miriam and Ropne. Outside this area, oil was extracted in Strilbychi and Staraya Sol. At most of these fields, oil horizons are at a depth of only 100-800 m. The gas and condensate are extracted at the field of Tanyavа in the wing of the Vytvytska Luska of the Berehova Skyba, which has been torn off by the thrust. In addition, a very large number of natural oil and gas manifestations - direct signs of oil and gas potential - have been recorded in the Skyba Zone. All this indicates the potential prospects of structures within the Skyba Zone, including shallow ones. The distribution area of Yamna sandstones is much larger than the area of these deposits. The distribution area of sandstones of Yamna is much larger than the area of these deposits. It occupies about half of the area of Skyba Zone. Part of it can be considered promising, removing areas where of Yamna sandstones are present on the day surface, although, even in such conditions, they are in some cases industrially oil-bearing (Strelbychi oil field). Sandstones of Yamna are characterized by satisfactory reservoir properties., The calculated porosity and permeability reach the maximum values at known deposits: 0.182 and 130 ∙ 10–3 microns2 respectively, and the estimated thickness of 13.5 m. In the Folded Carpathians and, especially, within the north-eastern fragments (Beregova, Oriv, Skoliv) in different years performed a large amount of field seismic surveys. On the basis of the obtained materials, for the first time in the Carpathian region structural constructions were made on the reflecting horizons in the Paleocene (Yamna Formation) and in the Stryi Formation of the Upper Cretaceous. This article evaluates the prospects of these research objects. The Khodkiv and Osichnyanska structures of Berehova Skyba are recommended for conducting search works.

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