Permeability prediction using stress sensitive petrophysical properties

Jones, Christopher; Somerville, James McLean; Smart, Brian George Davidson; Kirstetter, Olivier Hugues; Hamilton, Sally Ann; Edlmann, Katriona

doi:10.1144/petgeo.7.2.211

Cited by 12 publications

(5 citation statements)

References 8 publications

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“…After that, the permeability decreases smoothly with slowly decreased fracture apertures. High effective stress falls off particles attached to the pore surface at phase III, which can plug narrow throats or pores and decrease matrix permeability (Jones et al, 2001;Zhang et al, 2015;Geng et al, 2017). The stress sensitive coefficient of group 2 basically shares the same variation trend and origin with group 1, who has a smaller variation amplitude (about 2.2:1.3:1).…”

Section: Discussionmentioning

confidence: 99%

Seepage Behavior of Fractures in Paleogene Sandstone Reservoirs in Nanpu Sag, Bohai Bay Basin, Eastern China

Wang

Muhtar

et al. 2021

Front. Earth Sci.

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Natural fractures play an important role in the seepage system of Paleogene sandstone reservoirs at Nanpu Sag. Characteristics and formation mechanisms of natural fractures and stress-sensitivity permeability are comprehensively investigated and their impact on water injection is discussed based on core and log data (FMI and diplog data) as well as stress-sensitivity permeability measurement. Results show that high-angle shear fractures, including NE-SW strike fractures and NW-SE strike fractures, are widely developed in the study area, which were primarily developed during the late Paleogene and late Neogene. The present maximum horizontal principal stress is orientated at N60°–80°E, approximately parallel to the NE-SW fractures, contributing greatly to the seepage system at the early oilfield development stage. Fractures in the study area can be divided into three phases and are characterized by obvious stress-sensitivity permeability, which is closely related to fracture aperture and throat size. Since the fracture occurrence enhances stress sensitivity of permeability, it is necessary to regulate well pattern based on dynamic behaviors of fractured reservoirs at different development stages.

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Section: Discussionmentioning

confidence: 99%

Seepage Behavior of Fractures in Paleogene Sandstone Reservoirs in Nanpu Sag, Bohai Bay Basin, Eastern China

Wang

Muhtar

et al. 2021

Front. Earth Sci.

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“…17 This observation would account for the correspondence between the Leverett equivalent circular pore diameter L p and those parameters (a 1 , a 2 , a 3 ) that have been used to quantify the permeability response to stress. These latter parameters are constrained by the choice of a polynomial function to represent the reduction of permeability with stress.…”

Section: Discussionmentioning

confidence: 99%

The Stress Response of Permeability

Worthington¹

2004

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe response of intergranular permeability to applied hydrostatic stress is quantified through third-order polynomial fits to data from three loosely-to-moderately consolidated sandstone reservoirs from the same geological province. The derivatives of the fitted polynomials allow diverse permeability vs. stress behaviors to be identified and grouped. This grouping is quantified using composite stress-response parameters based on the polynomial regression coefficients, most notably their root mean square. This composite parameter shows a sufficiently good correspondence to Leverett's equivalent circular pore diameter L p to define exclusive "stress facies" in terms of ranges of L p in these formations. A permeability reduction factor from ambient conditions to effective reservoir stress is determined for each stress facies as a basis for correcting conventional core measurements. Although the results are formation-and stressfacies-specific, the approach has a general validity and can be adopted for any appropriate permeability vs. stress function. Principal benefits include better reservoir characterization and a sharper description of the change in permeability with stress as a basis for improved simulation models for development planning.

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“…Some studies have used overburden pressure to simulate pore pressure and investigate the influence of effective pressure on relative permeability. For example, Jones et al [10] explored how effective pressure affects relative permeability by subjecting samples to varying overburden pressures. The authors conducted laboratory experiments on core flooding, where overburden pressure was systematically adjusted to simulate reservoir permeabilities.…”

Section: Endpoint Of Water Relative Permeability Determination Throug...mentioning

confidence: 99%

EOR of heavy oil polymer on Alaska's North Slope: History matching challenges and solutions in a significant long-term water cut reduction

Shane Scott Namie,

Dongmei Wang

2024

GSC Adv. Res. Rev.

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In 2016, a pilot program in Alaska's Milne Point Field tested polymer flooding for heavy oil recovery. Using four wells in the Schrader Bluff reservoir, it aimed to assess its effectiveness in capturing heavy oil resources. Generally, polymer flooding can boost oil production by 10-15%, typically occurring 6-9 months after injection. However, in this case, it took over 24 months for a polymer breakthrough. The method proved highly effective, consistently reducing water content by over 40% and maintaining a low level below 20% for 18 months. Applying standard simulation methods, like history matching, became challenging due to this prolonged low water cut. The usual history-matching processes focus on relative permeability, permeability corrections, and skin effect modifications. Nevertheless, these alternatives proved ineffective. In response to the extended low water cut in Alaska's North Slope, a unique approach was suggested. This approach entails highlighting the low-end point (Krw) across multiple relative permeability curves and adjusting these values according to the water cut history. Additionally, the method takes into account permeability adjustments, Equation of State on analyzes of oil viscosity, J-function incorporation, and considers the potential for viscous fingering during the process. The pilot program displayed remarkable polymer flooding effectiveness, but its unique performance on the North Slope required a modified history-matching approach to simulate its success accurately.

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Permeability prediction using stress sensitive petrophysical properties

Cited by 12 publications

References 8 publications

Seepage Behavior of Fractures in Paleogene Sandstone Reservoirs in Nanpu Sag, Bohai Bay Basin, Eastern China

Seepage Behavior of Fractures in Paleogene Sandstone Reservoirs in Nanpu Sag, Bohai Bay Basin, Eastern China

The Stress Response of Permeability

EOR of heavy oil polymer on Alaska's North Slope: History matching challenges and solutions in a significant long-term water cut reduction

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