The Effect of Nitrogen Injection on Production Improvement in an Iranian Rich Gas Condensate Reservoir

Sadooni, Mostafa; Zonnouri, Ashkan

doi:10.1080/10916466.2014.992535

Cited by 12 publications

(5 citation statements)

References 15 publications

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“…Based on this complex phenomenon, a lot of studies have been approached to study on the best method in enhancing the hydrocarbon recovery [7][8][9][10][11][12]. One of those techniques is gas flooding.…”

Section: Introductionmentioning

confidence: 99%

Improved Hydrocarbon Recovery of a Lean Retrograde Gas Reservoir Under Propane Injection

Yusof

Fuad

Matali

2015

Day 1 Mon, November 09, 2015

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In most cases, retrograde gas reservoir in N Field which is located at the north of Malay Basin achieved 40-70% of recovery factor (RF) compared to dry gas reservoir, 80-90% of RF. Reservoir K, a lean retrograde gas reservoir of the N Field drained by Well 5 experience reduction in recovery (about 15% of RF) that is caused by a significant productivity loss, because of condensate banking. Condensate banking phenomenon (observed as skin) around the perforation zone restricted the flow of gas after the flowing bottom hole pressure falls below the dew point pressure. Therefore, the reduction in gas Inflow Performance Relationship (IPR) limits the Estimated Ultimate Recovery (EUR) of Reservoir K. It is the focus in this project to analyse the effect of miscible propane stimulated injection on the IPR, well deliverability and hence reservoir recovery. The retrograde gas reservoir model is integrated between E300, IPM PROSPER (well model) and IPM MBAL (reservoir model) software in reservoir performance prediction and forecasting study. Results show that there is 4% increment in gas recovery and 6% increment in condensate recovery after injection of propane to Reservoir K. There are about 4.2 million USD increment in revenue upon propane injection development. As conclusion, it is found that propane injection could minimize the condensate saturation that improves reservoir IPR and hydrocarbon recovery for both gas and condensate.

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Section: Introductionmentioning

confidence: 99%

Improved Hydrocarbon Recovery of a Lean Retrograde Gas Reservoir Under Propane Injection

Yusof

Fuad

Matali

2015

Day 1 Mon, November 09, 2015

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“…Besides, supercritical CO 2 could continuously destroy the colloidal structure of heavy oil, thereby further reducing the viscosity of heavy oil and enhancing its dissolving capability to CO 2 . , Hence, CO 2 is more easily dissolved in heavy oil. In contrast, N 2 is commonly regarded as an auxiliary fluid to enhance formation energy because of its stable properties and weak ability to reduce viscosity . Thus, a single N 2 source has a weak ability to dissolve in heavy oil.…”

Section: Resultsmentioning

confidence: 99%

“…In contrast, N 2 is commonly regarded as an auxiliary fluid to enhance formation energy because of its stable properties and weak ability to reduce viscosity. 99 Thus, a single N 2 source has a weak ability to dissolve in heavy oil.…”

Section: Fluid Dissolution In Heavymentioning

confidence: 99%

Diffusion and Dissolution Behaviors of CO₂, CH₄, and N₂ in Heavy Oil under High-Temperature and -Pressure Conditions: Insights into Heavy Oil Production via Multithermal Fluid Stimulation

Su,

Wang,

et al. 2023

Energy Fuels

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To comprehend heavy oil production well via the multithermal fluid stimulation technology, the diffusion and dissolution processes of CO2, CH4, and N2 in heavy oil were conducted under a temperature range of 308.15–423.15 K and bulk pressures up to 20 MPa. Accordingly, the diffusion coefficients and solubilities of CO2, CH4, and N2 were measured. Results indicated that the diffusion coefficients of CO2, CH4, and N2 in heavy oil increase with rising temperature and decrease with rising pressure. The diffusion capability of these fluids in heavy oil conforms to the order CH4 > CO2 > N2. Moreover, the solubility of CO2, CH4, and N2 in heavy oil is negatively related to temperature and positively related to pressure. The solubility of various fluids in heavy oil decreases in the sequence of CO2 > CH4 > N2. The diffusion and dissolution of CO2, CH4, and N2 could induce volume expansion, colloidal structure damage, intermolecular force alteration, gap filling, and light component extraction toward heavy oil, thereby promoting its quality and recovery. Overall, heavy oil production via the multithermal fluid stimulation technology is recommended to be implemented under high-temperature and -pressure conditions.

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“…Thus, it is important to investigate the potential performance of the EGR methods to alleviate condensate blockage and further increase the recovery factor in tight gas condensate reservoirs. Extensive study has been performed to maintain the reservoir pressure above the dew-point pressure in conventional gas condensate reservoirs, using techniques such as water injection (Matthews et al 1988), lean gas injection (Smith and Yarborough 1968; Abel et al 1970; Sigmund and Cameron 1977; Abasov et al 2000), CO 2 injection (Goricnik et al 1995; Narinesingh and Alexander 2014) and N 2 injection (Aziz 1983; Abdulwahab and Belhaj 2010; Sadooni and Zonnouri 2015). Usually, two schemes of fluid injection are employed for pressure maintenance in a condensate reservoir.…”

Section: Introductionmentioning

confidence: 99%

Enhancing recovery and sensitivity studies in an unconventional tight gas condensate reservoir

2018

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The recovery factor from tight gas reservoirs is typically less than 15%, even with multistage hydraulic fracturing stimulation. Such low recovery is exacerbated in tight gas condensate reservoirs, where the depletion of gas leaves the valuable condensate behind. In this paper, three enhanced gas recovery (EGR) methods including produced gas injection, CO 2 injection and water injection are investigated to increase the well productivity for a tight gas condensate reservoir in the Montney Formation, Canada. The production performance of the three EGR methods is compared and their economic feasibility is evaluated. Sensitivity analysis of the key factors such as primary production duration, bottom-hole pressures, and fracture conductivity is conducted and their effects on the well production performance are analyzed. Results show that, compared with the simple depletion method, both the cumulative gas and condensate production increase with fluids injected. Produced gas injection leads to both a higher gas and condensate production compared with those of the CO 2 injection, while waterflooding suffers from injection difficulty and the corresponding low sweep efficiency. Meanwhile, the injection cost is lower for the produced gas injection due to the on-site available gas source and minimal transport costs, gaining more economic benefits than the other EGR methods.

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The Effect of Nitrogen Injection on Production Improvement in an Iranian Rich Gas Condensate Reservoir

Cited by 12 publications

References 15 publications

Improved Hydrocarbon Recovery of a Lean Retrograde Gas Reservoir Under Propane Injection

Improved Hydrocarbon Recovery of a Lean Retrograde Gas Reservoir Under Propane Injection

Diffusion and Dissolution Behaviors of CO₂, CH₄, and N₂ in Heavy Oil under High-Temperature and -Pressure Conditions: Insights into Heavy Oil Production via Multithermal Fluid Stimulation

Enhancing recovery and sensitivity studies in an unconventional tight gas condensate reservoir

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The Effect of Nitrogen Injection on Production Improvement in an Iranian Rich Gas Condensate Reservoir

Cited by 12 publications

References 15 publications

Improved Hydrocarbon Recovery of a Lean Retrograde Gas Reservoir Under Propane Injection

Improved Hydrocarbon Recovery of a Lean Retrograde Gas Reservoir Under Propane Injection

Diffusion and Dissolution Behaviors of CO2, CH4, and N2 in Heavy Oil under High-Temperature and -Pressure Conditions: Insights into Heavy Oil Production via Multithermal Fluid Stimulation

Enhancing recovery and sensitivity studies in an unconventional tight gas condensate reservoir

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Product

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About

Diffusion and Dissolution Behaviors of CO₂, CH₄, and N₂ in Heavy Oil under High-Temperature and -Pressure Conditions: Insights into Heavy Oil Production via Multithermal Fluid Stimulation