A Novel Application of Standard Surveillance Techniques to Formation Damage Control by Identifying the Location of the Obstruction and Quantifying Skin Type

González, Fabio; González, Doris L.; Pietrobon, Marney; Yilmaz, Timur; Pecoraro, Jered; Stewart, Carlos; Duvivier, Giles

doi:10.2118/179010-ms

Cited by 7 publications

(1 citation statement)

References 5 publications

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“…An example of well surveillance to monitor formation damage evolution is presented in the literature [Gonzalez et al, 2016]. The main aspects of this monitoring technique are summarized as follows.…”

Section: Surveillance Of Damage Near Wellbore Using Pta and Mrtmentioning

confidence: 99%

Strategies to Monitor and Mitigate Asphaltene Issues in the Production System of a Gulf of Mexico Deepwater Subsea Development

González

Pietrobon

et al. 2016

Day 1 Mon, May 02, 2016

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An asphaltene threat has been identified in production wells located in a Gulf of Mexico (GOM) deepwater field. After production started from different reservoirs and the operating conditions for some of the wells reached the asphaltene precipitation onset, solid deposits were detected at different points in the production system, which caused production deferrals, disturbed the operating strategy of the field, and increased the operational expenditure. To remediate asphaltene deposition in deepwater subsea wells, a rig-less remediation costs up to $0.12 million (MM); a well intervention that requires a rig costs approximately $20 MM, and a vessel-based pumping remediation costs about $5 MM. These costs do not include the impact of production deferrals.A plan was developed to acquire and interpret the required information to properly understand and manage the asphaltene threat. The methodology includes:This paper presents an integrated approach to evaluate the key elements of asphaltene risk for deepwater projects, the strategy to manage the issues during production implementation, and lay out the aspects to be considered in the mitigation of the negative impact of asphaltene thread in the field development plan.

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Section: Surveillance Of Damage Near Wellbore Using Pta and Mrtmentioning

confidence: 99%

Strategies to Monitor and Mitigate Asphaltene Issues in the Production System of a Gulf of Mexico Deepwater Subsea Development

González

Pietrobon

et al. 2016

Day 1 Mon, May 02, 2016

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A Success Story of Production Improvement in a Deepwater GoM Field Based on Integration of Surveillance Techniques

González

Carmichael

et al. 2018

Day 1 Mon, November 12, 2018

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Integration of well and reservoir surveillance techniques: production measurements, reservoir fluid characterization, pressure transient analysis, production logging, relative permeability, and fractional flow are critical in understanding well and reservoir performance for an adequate well and field management specially in a high cost interventions environment. Well productivity deterioration for a specific well was identified based on production testing and well performance nodal analysis (NA). The productivity deterioration was then confirmed by means of pressure transient analysis (PTA). Standard diagnostic derivative analyses suggested that permeability decrease was the main source of performance detriment due to an apparent transmissibility reduction of 60%. Since water breakthrough took place before productivity impairment was acknowledged, the immediate reaction was to establish the hypothesis that effective permeability reduction due to relative permeability effects was the main reason for the impairment. A multilayer (ML) PTA type curve model together with fractional flow analysis did not support the relative permeability premise as the primary cause, leaving the potential for severe plugging of the reservoir rock as the predominant hypothesis. A production logging tool (PLT) was run confirming that about 60% of the completed interval was not producing at the expected levels. It was possible to separate the relative permeability effects from the plugging effects using the integrated technique described above. Relative permeability effects contributed to production impairment with an equivalent effective thickness of 14% and plugging effects impacted an equivalent effective thickness of 46%. A coiled tubing (CT) mud acid treatment was performed recovering approximately 65% of the transmissibility lost and decreasing formation skin from 16 to 9. This intervention delivered an instantaneous oil production benefit of approximately 7,000 STBOD. This analysis approach has been recommended to determine potential benefit of future intervention candidates. This paper presents an innovative approach to consider fractional flow as part of pressure transient analysis interpretation. This level of integration is not a common practice because PTA theory was developed for single phase and most of the commercial software products do not consider multiphase interpretations in analytical PTA. These limitations leave out the actual effect of relative permeability in the estimated transmissibility values.

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Understanding Reservoir Fluid Behavior to Mitigate Risk Associated to Asphaltene Deposition in the Reservoir Rock Near to Asphaltene Onset Pressure AOP in the Magwa Marrat Depleted Reservoir

Al-Obaidli¹,

Al-Nasheet²,

Snasiri³

et al. 2019

Day 4 Thu, March 21, 2019

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The Magwa-Marrat field started production early 1984 with an initial reservoir pressure of 9,600 psia Thirty-six (36) producer wells have been drilled until now. By 1999, when the field had accumulated ~92 MMSTB of produced oil and the reservoir pressure had declined to ~8000 psia, the field was shut-in until late 2003 due to concerns on asphaltene deposition in the reservoir that could cause irreversible damage and total recovery losses. The field was restarted in 2003 an it has been in production since then. By April 2018 the field had produced 220 MMSTBO, with the average reservoir pressure declined to 6,400 psia. As crude oil has been produced and the energy of the reservoir has depleted, the equilibrium of its fluid components has been disturbed and asphaltenes have precipitated out of the liquid phase and deposited in the production tubing. There is a concern that the reservoir will encounter asphaltene problems as the reservoir pressure drops further. The objective of this manuscript is to present the process to understand the reservoir fluids behavior as it relates to asphaltenes issues and develop a work frame to recognize and mitigate the risk of plugging the reservoir rock due to asphaltenes deposition with the end purpose of maximizing recovery while producing at the maximum field potential Data acquired during more than 30 years have been integrated and analyzed including 22 AOP measurements using gravimetric and solid detection system techniques, 17 PVT lab reports, 1 core- flooding study and 1 permeability/wettability study. Despite the wide range of AOP measured in different labs, it was possible to determine that the AOP for the Magwa-Marrat fluid is 5,600 ±500 psia and the saturation pressure is 3,200 ±200 psia. Results of this fluids review study indicates that it might be possible to deplete the reservoir pressure below the AOP while producing at high rates. Additional field testing and lab research have been proposed to 1) establish an adequate operating envelop for each well to optimize production and mitigate asphaltene deposition in the tubing to decrease downtime due to coiled tubing cleanouts which will reduce OPEX, 2) Support determination of a suitable reservoir pressure depletion to minimize CAPEX by implementing a pressure support project at an optimum reservoir pressure, and 3) Establish an appropriate field development strategy to produce the field at its maximum potential without jeopardizing the health of the reservoir while optimizing ultimate recovery

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A Novel Application of Standard Surveillance Techniques to Formation Damage Control by Identifying the Location of the Obstruction and Quantifying Skin Type

Cited by 7 publications

References 5 publications

Strategies to Monitor and Mitigate Asphaltene Issues in the Production System of a Gulf of Mexico Deepwater Subsea Development

Strategies to Monitor and Mitigate Asphaltene Issues in the Production System of a Gulf of Mexico Deepwater Subsea Development

A Success Story of Production Improvement in a Deepwater GoM Field Based on Integration of Surveillance Techniques

Understanding Reservoir Fluid Behavior to Mitigate Risk Associated to Asphaltene Deposition in the Reservoir Rock Near to Asphaltene Onset Pressure AOP in the Magwa Marrat Depleted Reservoir

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