Improved Oil Recovery in Mature Oil and Gas Fields Using Twin-Screw Multiphase Pumps

2010 ◽  
Author(s):  
Dietrich Mueller-Link
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Improved Oil Recovery ◽  
Oil And Gas Fields ◽  
Twin Screw ◽  
Gas Fields

Peculiarity of Reserves Production and Oil Recovery of Oil and Gas Fields

2005 ◽  
Author(s):  
N.A. Cheremisin ◽  
P.A. Efimov ◽  
A.A. Klimov ◽  
R.A. Bulatov
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Oil And Gas Fields ◽  
Gas Fields

The Pyrenees development: a new oil development for Western Australia

2010 ◽  
Vol 50 (1) ◽  
pp. 241
Author(s):  
Tony Slate ◽  
Ralf Napalowski ◽  
Steve Pastor ◽  
Kevin Black ◽  
Robert Stomp
Keyword(s):  
Western Australia ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Flow Meters ◽  
Field Development ◽  
Oil And Gas Fields ◽  
Sand Control ◽  
Concurrent Development ◽  
Gas Fields ◽  
Offshore Oil

The Pyrenees development comprises the concurrent development of three oil and gas fields: Ravensworth, Crosby and Stickle. The fields are located in production licenses WA-42-L and WA-43-L, offshore Western Australia, in the Exmouth Sub-basin. The development will be one of the largest offshore oil developments in Australia for some time. It is a complex subsea development consisting of a series of manifolds, control umbilicals and flexible flowlines tied back to a disconnectable floating production, storage and offloading (FPSO) vessel. The development involves the construction of 17 subsea wells, including 13 horizontal producers, three vertical water disposal wells and one gas injection well. The project is presently on production with first oil achieved during February 2010. This paper gives an overview of the field development and describes the engineering and technologies that have been selected to enable the economic development of these fields. The Pyrenees fields are low relief, with oil columns of about 40 metres in excellent quality reservoirs of the Barrow Group. Two of the fields have small gas caps and a strong bottom water drive common to all fields is expected to assist recovery. The oil is a moderate viscosity, low gas-to-oil ratio (GOR), 19°API crude. Due to the geometry of the reservoirs, the expected drive mechanism and the nature of the crude, effective oil recovery requires maximum reservoir contact and hence the drilling of long near horizontal wells. Besides the challenging nature of well construction, other technologies adopted to improve recovery efficiency and operability includes subsea multiphase flow meters and sand control with inflow control devices.

A contribution to the petrophysical knowledge of the Lourinhã Formation as an analogue for the Statfjord Formation in the North Sea oil and gas fields

2020 ◽  
Vol 27 (1) ◽  
pp. petgeo2019-132
Author(s):  
Marco Ludovico-Marques
Keyword(s):  
North Sea ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Effective Porosity ◽  
Average Value ◽  
The North ◽  
Oil And Gas Fields ◽  
The North Sea ◽  
Northern North Sea ◽  
Gas Fields

The Lourinhã Formation in the western region of Portugal is an analogue for the Statfjord Formation in the oil and gas fields of the Norwegian Northern North Sea. This petrophysics study encompasses a specific sandstone variety (M variety) of the Lourinhã Formation. This lithic arkose shows an average value of effective porosity of 18.5% and a permeability range of 20–30 mD, and is representative of the distribution range in the petrophysics models of the reservoirs of the Statfjord Formation. The petrographical, physical and mechanical characterization of the M variety sandstone is compared with the main features of the oil- and gas-producing sandstones of the Statfjord Formation in a reference well in the Norwegian Northern North Sea. Efficient enhanced oil recovery (EOR) projects in the oil and gas fields of the Norwegian Gullfaks hub are always needed, and this study intends to provide a contribution to that endeavour.

scholarly journals Study and apply the advanced analysis algorithm to screen the optimal enhanced oil recovery solution for oil and gas fields in Viet Nam

2021 ◽  
Vol 62 (3a) ◽  
pp. 17-29
Author(s):  
Long Hoang ◽  
Thang Viet Trinh ◽  
Truong Hung Trieu ◽  
Quy Minh Nguyen ◽  
Ngoc Quy Pham ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Large Scale ◽  
Oil And Gas ◽  
Modern Technology ◽  
Oil And Gas Fields ◽  
Depth Analysis ◽  
The World ◽  
Advanced Analysis ◽  
Gas Fields

Applying the methods of enhanced oil recovery (EOR) for oil and gas fields has always many risks of economic and technology because EOR projects are influenced by many characteristic factors of the reservoir such as structure of reservoir, reservoir formation, geological properties, parameters of reservoir engineering, production technology to EOR application. Some EOR methods have been successfully applied in the world, but when these methods conduct in specific reservoir with different geological characteristics, tight production conditions have resulted in failures and ineffective economic, even caused dreadful aftermath to be handled in operations. Researches, evaluations and EOR applications in Vietnam are limited and only carried out on a laboratory scale. Therefore, the ability to be applied the EOR modern technology with a large scale or full field still faces many difficulties and the feasibility of projects is not high enough. The authors have been analysed all EOR projects successfully that applied many oil and gas fields in the world and then building EOR database. Based on EOR database, a study has been conducted on statistical analysis to build EOR screening criteria for reservoir parameters from past to now. The study also combined in-depth analysis algorithms such as Fuzzy, K - mean, PCA Artificial Intelligence to screen the optimal EOR method for sandstone reservoirs of Cuu Long Basin.

scholarly journals An evaluation of key challenges of CO2 transportation with a novel Subsea Shuttle Tanker

2021 ◽  
Vol 1201 (1) ◽  
pp. 012078
Author(s):  
Y Ma ◽  
Y Xing ◽  
T H Hemmingsen
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Autonomous Underwater Vehicle ◽  
Material Selection ◽  
Hydrate Formation ◽  
Oil And Gas Fields ◽  
Permanent Storage ◽  
Offshore Oil And Gas ◽  
Co2 Transportation ◽  
Gas Fields

Abstract Recently, a novel Subsea Shuttle Tanker (SST) concept has been proposed to transport carbon dioxide (CO2) from ports to offshore oil and gas fields for either permanent storage or enhanced oil recovery (EOR). SST is a large autonomous underwater vehicle that travels at a constant water depth away from waves. SST has some key advantages over subsea pipelines and tanker ships when employed at marginal fields. It enables carbon storage in marginal fields which do not have sufficient volumes to justify pipelines. Further, in contrast to ships, SST does not require the use of a permanently installed riser base. This paper will evaluate the key challenges of using such vessel for CO2 transportation. It discusses the most important properties such as thermodynamic properties, purity, and hydrate formation of CO2 at different vessel-transportation states in relation to cargo sizing, material selection, and energy consumption.

scholarly journals Technologies that have transformed the Exmouth into Australia

2015 ◽  
Vol 55 (1) ◽  
pp. 233 ◽  
Author(s):  
Richard Loro ◽  
Robin Hill ◽  
Mark Jackson ◽  
Tony Slate
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Vincent Van Gogh ◽  
Variable Permeability ◽  
Oil And Gas Fields ◽  
Sand Control ◽  
Oil Water ◽  
Gas Fields ◽  
Clastic Reservoirs ◽  
Made In

The oil and gas fields of the Exmouth Sub-basin, offshore WA, have presented a number of significant challenges to their exploitation since the first discoveries of heavy oil and lean gas were made in the late 1980s and early 1990s. Presently, some 20 oil and gas fields have been discovered in a variety of Late Jurassic to Cretaceous clastic reservoirs from slope turbidites to deltaic sands. Discovered oils are typically heavily biodegraded with densities ranging from 14–23° API and moderate viscosity. Seismic imaging is challenging across some areas due to pervasive multiples and gas escape features, while in other areas resolution is excellent. Most reservoirs are poorly cemented to unconsolidated and thus require sand control. Modest oil columns, most with gas caps, and variable permeability, present challenges for both maximising oil recovery and minimising the influx of water and gas. Oil-water emulsions also present difficulties for both maximising oil rate and metering production. To date, more than 300 MMbbls have been produced from five developments (Enfield, Stybarrow, Vincent, Van Gogh and Pyrenees), and in 2013 the Macedon gasfield began production. This peer-reviewed paper focuses on the variety of technologies—geoscience, reservoir, drilling and production—that have underpinned the development of these challenging fields and in doing so, transformed the Exmouth into Australia’s premier oil producing basin.

scholarly journals Improving the efficiency of well workover solutions for the elimination of behind-the-casing flows

2021 ◽  
Vol 266 ◽  
pp. 01011
Author(s):  
L.G. Rakhmaev ◽  
V.D. Odayev
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Cross Flow ◽  
Operating Costs ◽  
Injection Wells ◽  
Oil Companies ◽  
Oil And Gas Fields ◽  
Low Efficiency ◽  
Gas Fields ◽  
Modern Technologies

The article deals with the increase of profitability of water shutoff treatment (WST), which is used to eliminate behind-the-casing flows (cross-flow) in production and injection wells. It is presented that modern technologies of water shut-off works have low efficiency (success rate), especially in liquidation of non-perforating interval. Inefficient (wasteful) injection is currently one of the main problems in the development of oil and gas fields, as it significantly reduces the oil recovery factor in addition to the huge costs for oil companies for injection (operating costs). The article presents the results of hydrodynamic research and proposes methods for determining the presence of behind-the-casing flows (BCF) and methods for detecting wasteful injection without geophysical well-logging (a non-standard approach). The article also presents equipment for the elimination of the behind-the-casing flow and technology of its implementation.

CO2 Pipelines: A Thermodynamic Modeling with Pre-Salt Applications

2016 ◽  
Vol 830 ◽  
pp. 57-64 ◽  
Author(s):  
José Luiz de Medeiros ◽  
Ofélia Queiroz Fernandes de Araújo
Keyword(s):  
Compressible Flow ◽  
Oil Recovery ◽  
Carbon Capture ◽  
Oil And Gas ◽  
Axial Direction ◽  
Oil And Gas Fields ◽  
High Pressure Co2 ◽  
Offshore Oil And Gas ◽  
Co2 Flow ◽  
Gas Fields

This paper approaches CO2 pipelines operating with high dense compressible flow for Enhanced Oil Recovery (EOR) and/or Carbon Capture & Geological Storage (CCGS). The idiosyncrasies of high pressure CO2 flow are discussed and an appropriate and rigorous steady-state compressible flow pipeline model is disclosed. The model gives three Ordinary Differential Equations (ODE) which result from one-dimensional, one-phase, Mass, Momentum & Energy Balances along the pipeline axial direction. This ODE set is numerically integrated leading to profiles of temperature, pressure and inventory along the pipeline, which are basic for design. An example is explored in the context of a hypothetical EOR CO2 pipeline aligned to the production of CO2 rich natural gas in the Pre-Salt offshore oil and gas fields on the southeast coast of Brazil.

Potential of recovering elements from produced water at oil and gas fields, British Columbia, Canada

CIM Journal ◽  
2018 ◽  
Vol 9 (4) ◽  
pp. 195-214
Author(s):  
G. J. Simandl ◽  
C. Akam ◽  
M. Yakimoski ◽  
D. Richardson ◽  
A. Teucher ◽  
...  
Keyword(s):  
British Columbia ◽  
Oil And Gas ◽  
Produced Water ◽  
Oil And Gas Fields ◽  
Gas Fields

Аdaptability of building structures for oil and gas fields

2017 ◽  
pp. 100-103
Author(s):  
A.V. Antonov ◽  
◽  
Yu.V. Maksimov ◽  
A.N. Korkishko ◽  
◽  
...  
Keyword(s):  
Oil And Gas ◽  
Building Structures ◽  
Oil And Gas Fields ◽  
Gas Fields
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