Production-Induced Stresses from Timelapse Timeshifts – A Geomechanics Case Sstudy from the Franklin &amp; Elgin Fields

Hawkins, Keith; Ben-Brahim, L.; Howe, Sharon; Tindle, C.; Hollingworth, S.; Taylor, N.; Joffroy, G.; Conroy, Graham; Onaisi, A.

doi:10.3997/2214-4609.201401550

Cited by 4 publications

(2 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The increased temperature and pressure cause a change of stress and could eventually lead to the rock failure in/outside of the reservoir. 17,18 , assuming uniaxial compaction to cumpute vertical stress changes. Understanding the geomechanical impact of the thermal recovery process would help optimize the injection pressure while keeping the caprock integrity, and finally improve the hydrocarbon recovery.…”

Section: Introductionmentioning

confidence: 99%

Fluid Production and Injection Induced Stress Changes Using Reservoir Volume Changes Inverted From Tiltmeter-Based Surface Deformation Measurements

Du¹,

Maxwell²,

Warpinski³

2007

Proceedings of SPE Annual Technical Conference and Exhibition

View full text Add to dashboard Cite

fax 01-972-952-9435. AbstractProduction and injection induced stress changes are in some circumstances, an important issue in field development and reservoir management. Previously, induced poroelastic stresses have been calculated by integrating the center of a dilatation source over a certain reservoir region. 1,2 However, this approach has difficulty when the observation points lie inside the reservoir blocks.This paper presents the application of an analytical stress solution due to an initial (eigenstrain or transformation) strain in a cuboid 3 to calculate the induced stress changes using the volume changes inverted from the tiltmeter-based surface deformation measurements. 4,5 Arbitrary strain volumes can then be constructed from an assemblage of discrete cuboids, allowing stresses both within and outside the strain zone. The stress calculation formulation was applied to a field case study where a warm-up phase of steam injection into a steam assisted gravity drainage (SAGD) well pair was monitored with an array of surface tiltmeters and a downhole microseismic array 6 . Using a Mohr-Coulomb failure criterion, predicted locations of failure are compared with the actual locations from the microseismic monitoring.

show abstract

Section: Introductionmentioning

confidence: 99%

Fluid Production and Injection Induced Stress Changes Using Reservoir Volume Changes Inverted From Tiltmeter-Based Surface Deformation Measurements

Du¹,

Maxwell²,

Warpinski³

2007

Proceedings of SPE Annual Technical Conference and Exhibition

View full text Add to dashboard Cite

show abstract

“…It could be a processing artifact as processing applied to time-lapse data concentrated less on reflections coming from beneath reservoir 'A'; however it could also be caused by stretching in the underburden. Hawkins et al (2007) performed geo-mechanical modelling over three different fields from the North Sea (near each other, at depths of 5100-5600m) and inverted the time-lapse travel time shifts into respective 4D stress changes. They found almost 5 ms delay in the overburden of two reservoirs while the third reservoir exhibited only 2 ms time-shift, and that the third reservoir exhibited stronger travel-time shifts in the underburden than in the overburden.…”

Section: Resultsmentioning

confidence: 99%

Time Lapse Seismic Observations and Effects of Reservoir Compressibility at Teal South Oil Field

Islam¹

View full text Add to dashboard Cite

Microseismicity sensing of CO<inf>2</inf>-enhanced oil recovery and sequestration in an oil reservoir: Citronelle field, Alabama, USA

Liu

Chen

Wang

2011

2011 International Symposium on Water Resource and Environmental Protection

View full text Add to dashboard Cite

This paper reports a study that proposes the use of Geophysical testing techniques to monitor the effects of Carbon Dioxide (CO 2 ) injection into a test well in the Citronelle Oil Field in Mobile, Alabama, for both CO 2 sequestration and enhanced oil recovery. The Citronelle Oil Field is the largest conventional oil field in the State of Alabama and is currently in the tertiary oil production stage. This research is part of a proposed research to evaluate the Rodessa Formation (depth 3,505.2 meters) for its potential to recover additional oil through enhanced oil recovery using carbon dioxide (CO 2 EOR), as well as its CO 2 sequestration potential.The goal of the Geophysical testing is to determine if seismic measurements are capable of detecting changes in the geologic formation and the presence and migration of CO 2 during and after the injection. Comprehensive geophysical studies will be conducted based on surface seismicity testing using linear arrays of seismometers to detect and observe wave propagations and reflections through the soil medium. Since the Citronelle oil field is located in the vicinity of a concentrated population; innovative seismic measurement techniques that can reduce disturbance to the neighborhoods, including wireless transducers and ambient excitation, are to be explored.

show abstract

Production-Induced Stresses from Timelapse Timeshifts – A Geomechanics Case Sstudy from the Franklin & Elgin Fields

Cited by 4 publications

References 0 publications

Fluid Production and Injection Induced Stress Changes Using Reservoir Volume Changes Inverted From Tiltmeter-Based Surface Deformation Measurements

Fluid Production and Injection Induced Stress Changes Using Reservoir Volume Changes Inverted From Tiltmeter-Based Surface Deformation Measurements

Time Lapse Seismic Observations and Effects of Reservoir Compressibility at Teal South Oil Field

Microseismicity sensing of CO<inf>2</inf>-enhanced oil recovery and sequestration in an oil reservoir: Citronelle field, Alabama, USA

Contact Info

Product

Resources

About