Developing the world’s largest CO2 Injection System – a history of the Gorgon Carbon Dioxide Injection System

2021 ◽  
Author(s):  
Mark Trupp ◽  
Scott Ryan ◽  
Ishtar Barranco Mendoza ◽  
Daniel Leon ◽  
Leigh Scoby-Smith
Keyword(s):  
Carbon Dioxide ◽  
Injection System ◽  
Co2 Injection ◽  
Carbon Dioxide Injection ◽  
System A ◽  
History Of

A Laboratory Investigation of the Effect of Ethanol-Treated Carbon Dioxide Injection on Oil Recovery and Carbon Dioxide Storage

SPE Journal ◽  
2021 ◽  
pp. 1-17
Author(s):  
Saira ◽  
Emmanuel Ajoma ◽  
Furqan Le-Hussain
Keyword(s):  
Carbon Dioxide ◽  
Oil Recovery ◽  
Carbon Capture ◽  
Molar Fraction ◽  
Co2 Injection ◽  
Carbon Dioxide Injection ◽  
Treated Carbon ◽  
Carbon Dioxide Co2 ◽  
And Storage ◽  
Experimental Runs

Summary Carbon dioxide (CO2) enhanced oil recovery is the most economical technique for carbon capture, usage, and storage. In depleted reservoirs, full or near-miscibility of injected CO2 with oil is difficult to achieve, and immiscible CO2 injection leaves a large volume of oil behind and limits available pore volume (PV) for storing CO2. In this paper, we present an experimental study to delineate the effect of ethanol-treated CO2 injection on oil recovery, net CO2 stored, and amount of ethanol left in the reservoir. We inject CO2 and ethanol-treated CO2 into Bentheimer Sandstone cores representing reservoirs. The oil phase consists of a mixture of 0.65 hexane and 0.35 decane (C6-C10 mixture) by molar fraction in one set of experimental runs, and pure decane (C10) in the other set of experimental runs. All experimental runs are conducted at constant temperature 70°C and various pressures to exhibit immiscibility (9.0 MPa for the C6-C10 mixture and 9.6 MPa for pure C10) or near-miscibility (11.7 MPa for the C6-C10 mixture and 12.1 MPa for pure C10). Pressure differences across the core, oil recovery, and compositions and rates of the produced fluids are recorded during the experimental runs. Ultimate oil recovery under immiscibility is found to be 9 to 15% greater using ethanol-treated CO2 injection than that using pure CO2 injection. Net CO2 stored for pure C10 under immiscibility is found to be 0.134 PV greater during ethanol-treated CO2 injection than during pure CO2 injection. For the C6-C10 mixture under immiscibility, both ethanol-treated CO2 injection and CO2 injection yield the same net CO2 stored. However, for the C6-C10 mixture under near-miscibility,ethanol-treated CO2 injection is found to yield 0.161 PV less net CO2 stored than does pure CO2 injection. These results suggest potential improvement in oil recovery and net CO2 stored using ethanol-treated CO2 injection instead of pure CO2 injection. If economically viable, ethanol-treated CO2 injection could be used as a carbon capture, usage, and storage method in low-pressure reservoirs, for which pure CO2 injection would be infeasible.

scholarly journals Investigation of the influence of the carbon dioxide (CO2) injection rate on the activity of the water pressure system during gas condensate fields development

2021 ◽  
Vol 230 ◽  
pp. 01011
Author(s):  
Serhii Matkivskyi ◽  
Oleksandr Kondrat ◽  
Oleksandr Burachok
Keyword(s):  
Carbon Dioxide ◽  
Water Pressure ◽  
Gas Production ◽  
Gas Condensate ◽  
Co2 Injection ◽  
Final Decision ◽  
Water Production ◽  
Carbon Dioxide Injection ◽  
Pressure System ◽  
Water Contact

The development of gas condensate fields under the conditions of elastic water drive is characterized by uneven movement of the gas-water. Factors of hydrocarbon recovery from producing reservoirs which are characterized by the active water pressure drive on the average make up 50-60%. To increase the efficiency of fields development, which are characterized by an elastic water drive, a study of the effect of different volumes of carbon dioxide injection at the gas-water contact on the activity of the water pressure system and the process of flooding producing wells was carried out. Using a three-dimensional model, the injection of carbon dioxide into wells located at the boundary of gas-water contact with flow rates from 20 to 500 thousand m3/day was investigated. Analyzing the simulation data, it was found that increasing the volume of carbon dioxide injection provides an increase in accumulated gas production and a significant reduction in water production. The main effect of the introduction of this technology is achieved by increasing the rate of carbon dioxide injection to 300 thousand m3/day. The set injection rates allowed us to increase gas production by 67% and reduce water production by 83.9% compared to the corresponding indicators without injection of carbon dioxide. Taking into account above- mentioned, the final decision on the introduction of carbon dioxide injection technology and optimal technological parameters of producing and injection wells operation should be made on the basis of a comprehensive technical and economic analysis using modern methods of the hydrodynamic modeling of reservoir systems.

scholarly journals Mathematical Model of Carbon Dioxide Injection into a Porous Reservoir Saturated with Methane and Its Gas Hydrate

Energies ◽  
2020 ◽  
Vol 13 (2) ◽  
pp. 440 ◽  
Author(s):  
Marat K. Khasanov ◽  
Guzal R. Rafikova ◽  
Nail G. Musakaev
Keyword(s):  
Carbon Dioxide ◽  
Mass Transfer ◽  
Porous Medium ◽  
Diffusion Coefficient ◽  
Gas Hydrate ◽  
Co2 Injection ◽  
Carbon Dioxide Injection ◽  
Reservoir Permeability ◽  
Replacement Process ◽  
Porous Reservoir

In this paper, the process of methane replacement in gas hydrate with carbon dioxide during CO2 injection into a porous medium is studied. A model that takes into account both the heat and mass transfer in a porous medium and the diffusion kinetics of the replacement process is constructed. The influences of the diffusion coefficient, the permeability and extent of a reservoir on the time of full gas replacement in the hydrate are analyzed. It was established that at high values of the diffusion coefficient in hydrate, low values of the reservoir permeability, and with the growth of the reservoir length, the process of the CH4-CO2 replacement in CH4 hydrate will take place in the frontal regime and be limited, generally, by the filtration mass transfer. Otherwise, the replacement will limited by the diffusion of gas in the hydrate.

Optimization of the Cement Slurry Compositions With Addition of Zeolite for Cementing Carbon Dioxide Injection Wells

2015 ◽  
Author(s):  
Krunoslav Sedić ◽  
Nediljka Gaurina-Medjimurec ◽  
Borivoje Pašić
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Co2 Injection ◽  
Carbon Dioxide Injection ◽  
Cement Slurry ◽  
Gas Reservoirs ◽  
Injection Wells ◽  
Standard Size ◽  
Well Integrity ◽  
Well Cement

Well integrity related to carbon dioxide injection into depleted oil and gas reservoirs can be compromised by corrosion which can affect casing, downhole and surface equipment and well cement. Impact on well cement can cause overall degradation of set cement and lead to migration of carbon dioxide back to the surface. Thus, special types of cements should be used. One of the acceptable solutions is application of cement blends based on a mixture of Portland cement and pozzolans. The present paper deals with optimization of the cement slurry design containing zeolite which is nowadays widely used due to its high pozzolan activity potential. Cement blends containing 20%, 30% and 40% zeolite clinoptilolite were used. Cement slurries were optimized for application in slim hole conditions on CO2 injection wells on Žutica and Ivanić oil fields in Croatia (Europe), where an old and deteriorated production casing was re-lined with new smaller sized one. Results obtained by this study suggest that cement slurry containing zeolite can be optimized for application in well conditions related to CO2 injection and underground storage, ranging from a slim hole to standard size casing cement jobs which leads to an improvement of well integrity related to CO2 injection.

scholarly journals A Simple Carbon Dioxide Injection System for Photosynthetic Studies

1974 ◽  
Vol 54 (4) ◽  
pp. 649-651 ◽  
Author(s):  
David J. Oliver ◽  
Stewart I. Cameron ◽  
Michail Schaedle
Keyword(s):  
Carbon Dioxide ◽  
Injection System ◽  
Carbon Dioxide Injection

Reservoir Geomechanical Modeling and Ground Uplift During CO2 Injection Into Khuff Reservoir

2019 ◽  
Author(s):  
Sikandar Khan ◽  
Yehia Khulief ◽  
Abdullatif Al-Shuhail
Keyword(s):  
Carbon Dioxide ◽  
Carbonate Reservoir ◽  
Comsol Multiphysics ◽  
Co2 Injection ◽  
Low Permeability ◽  
Carbon Dioxide Injection ◽  
Injection Parameters ◽  
Coulomb Failure ◽  
Coulomb Failure Criterion ◽  
The Stability

Abstract In this investigation, coupled-geomechanical modeling is performed using the COMSOL Multiphysics software, during carbon dioxide injection into the deep Khuff carbonate reservoir. Khuff reservoir is a carbonate reservoir that is capped by the low permeability Sudair shale geological layer. The main objective of the study was to evaluate safe values of the carbon dioxide injection parameters for the Khuff reservoir that will act as a benchmark for the similar reservoirs and injection scenarios around the globe. Carbon dioxide was injected for a period of 10 years into the reservoir and the corresponding variations in the reservoir pore-pressure and ground uplift was evaluated. The Mohr-Coulomb failure criterion was utilized to perform the stability analysis for the Khuff reservoir during carbon dioxide injection.

scholarly journals Solving the carbon-dioxide buoyancy challenge: The design and field testing of a dissolved CO2 injection system

2015 ◽  
Vol 37 ◽  
pp. 213-219 ◽  
Author(s):  
Bergur Sigfusson ◽  
Sigurdur R. Gislason ◽  
Juerg M. Matter ◽  
Martin Stute ◽  
Einar Gunnlaugsson ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Field Testing ◽  
Injection System ◽  
Co2 Injection
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