Low frequency models for seismic inversions: strategies for success

Pendrel, John

doi:10.1190/segam2015-5843272.1

Cited by 13 publications

(6 citation statements)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…This low frequency model assures the inversion is consistent with the background geological information by including sub-seismic frequencies in the Bnal computation. This stabilizes the inversion workCow by introducing temporal limits and spatial variations to the interpreted seismic horizons (Dutta and Khazanehdari 2006;Pendrel 2015;Azevedo and Soares 2017). Due to the non-uniqueness of seismic inversion, higherthan and lower-than-real seismic frequencies will appear in the inverted data.…”

Section: Model-based Seismic Inversionmentioning

confidence: 93%

“…It is worth stressing that band-limited seismic data do not contain the original low frequency spectrum of the acquired signal, as it is Bltered out ('cut-oA') during processing (Ray and Chopra 2015;Azevedo and Soares 2017). Without this lower frequency content, the quantitative prediction of reservoir properties is somewhat inaccurate and non-unique (Pendrel 2015;Sams and Carter 2017).…”

Section: Inversion Methodologymentioning

confidence: 99%

See 1 more Smart Citation

Application of model based post-stack inversion in the characterization of reservoir sands containing porous, tight and mixed facies: A case study from the Central Indus Basin, Pakistan

et al. 2021

View full text Add to dashboard Cite

Porosity is a key parameter for reservoir evaluation. Inferring the porosity from seismic data is often challenging and prone to uncertainties due to number of factors. The main aim of this paper is to show the applicability of seismic inversion on old vintage seismic data to map spatial porosity at reservoir level. 3D-seismic and wireline log data are used to map the reservoir properties of the Lower Goru productive sands in the Gambat Latif block, Central Indus Basin, Pakistan. The Lower Goru formation was interpreted with the help of seismic and well data. Interpreted horizons are thus further used in model-based seismic inversion techniques to map the spatial distribution of porosity. Well-log data are used in the construction of low acoustic impedance models. Calibration of reservoir porosity with inverted acoustic impedance is achieved through well-log data. The results from model-based inversion reasonably estimate the porosity distribution within the C-sand interval of the Lower Goru Member. After post-stack inversion, the porosity values at wells Tajjal-01, Tajjal-02 and Tajjal-03 are 10%, 8% and 12%, respectively. Porosity values calculated from post-stack inversion at the corresponding well locations are in good agreement with the borehole-derived porosity.

show abstract

Section: Model-based Seismic Inversionmentioning

confidence: 93%

Section: Inversion Methodologymentioning

confidence: 99%

Application of model based post-stack inversion in the characterization of reservoir sands containing porous, tight and mixed facies: A case study from the Central Indus Basin, Pakistan

et al. 2021

View full text Add to dashboard Cite

show abstract

“…The prior impedances of Ip and Is incorporate the background knowledge of the subsurface into the inversion results by employing well data information in a stratigraphic grid (Doyen, 2007;de Figueiredo et al, 2017). The interpolation of well logs between well locations behaves as LFMs of filtered elastic properties that highly impact the differentiation of litho-facies on inverted elastic properties (Bosch et al, 2009;Kumar and Negi 2012;Pendrel, 2015). Also, the prior impedances are taken as fundamental models in the stochastic inversion procedure for compensating the missing low frequencies (about 6/10 Hz) and used to evaluate the fitting degree between modeled and observed elastic properties in the likelihood function (Zhang et al, 2021).…”

Section: Bayesian Stochastic Inversionmentioning

confidence: 99%

Bayesian stochastic inversion with petro-elastic relation to quantify thin gas sands of Khadro Formation, Zamzama gas field

et al. 2022

View full text Add to dashboard Cite

A challenging situation in reservoir characterization arises when reservoirs occur below the vertical resolution of seismic, such as the 6 m gas-prone sands of the heterogenous Khadro Formation. This formation is the Zamzama gas field's secondary reservoir and needs detailed evaluation for optimum production of the field as the deeper primary reservoir of Pab sandstone is facing the problem of early water encroachment in its producing wells. The characterization of thin heterogeneous gas-bearing facies is hampered by the insensitivity of well-bore recording tools in precisely capturing elastic properties. Consequently, petro-elastic models (PEMs) of identified facies are generated that produce consistent elastic responses and discriminate facies in their true elastic domains. The resolution of seismic elastic properties is enhanced to illuminate the thin gas-bearing sands by adopting a Bayesian stochastic inversion process in collaboration with PEMs modeled elastic responses on a fine-scale stratigraphic grid. In addition, the Bayesian framework is used to estimate the litho-facies probability cubes to mitigate the drilling risks by integrating highly sampled posterior elastic volumes, modeled elastic logs, and geologic information of identified litho-facies. The outcomes included prospect identification at the drilled well locations that need to be perforated, while new potential zones are present for additional wells.

show abstract

“…Besides, the quality of the available seismic velocity is doubtful and it does not conform to the geological structure. Thus, a simple shale compaction trend workflow was selected with iterative inversion and update of the low frequency information through simultaneous inversion and Bayesian facies estimation procedure (Pendrel, 2015).…”

Section: Seismic Inversionmentioning

confidence: 99%

Geostatistical reservoir characterization of deepwater channel, offshore Malaysia

Kurniawan

Zeb

Ting

et al. 2016

SEG Technical Program Expanded Abstracts 2016

View full text Add to dashboard Cite

A quantitative interpretation was carried out in order to improve geological model and de-risk the prospect in the next exploration drilling campaign. Recently drilled exploration wells based on conventional seismic interpretation drilled through channel levee instead of the targeted channel core. Vertical resolution, reservoir quality, distribution and continuity of the channel feature are the main risks. A geostatistical inversion guided by rock physics modeling and deterministic inversion has been conducted to improve resolution, analyze the rock character and deliver probabilistic reservoir properties analysis as part of risk assessment. The results show that this technique improves the mapping of channel features associated with porosity and volume of clay distribution in comparison to the deterministic inversion or conventional seismic interpretation.

show abstract

Low frequency models for seismic inversions: strategies for success

Cited by 13 publications

References 3 publications

Application of model based post-stack inversion in the characterization of reservoir sands containing porous, tight and mixed facies: A case study from the Central Indus Basin, Pakistan

Application of model based post-stack inversion in the characterization of reservoir sands containing porous, tight and mixed facies: A case study from the Central Indus Basin, Pakistan

Bayesian stochastic inversion with petro-elastic relation to quantify thin gas sands of Khadro Formation, Zamzama gas field

Geostatistical reservoir characterization of deepwater channel, offshore Malaysia

Contact Info

Product

Resources

About