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Impact of petrophysical properties o...

Seals, Kelsey L.

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Impact of petrophysical properties on hydraulic fracture analysis.

Record Type:	Electronic resources : Monograph/item
Title/Author:	Impact of petrophysical properties on hydraulic fracture analysis./
Author:	Seals, Kelsey L.
Published:	Ann Arbor : ProQuest Dissertations & Theses, : 2017,
Description:	172 p.
Notes:	Source: Masters Abstracts International, Volume: 56-03.
Contained By:	Masters Abstracts International56-03(E).
Subject:	Petroleum engineering. -
Online resource:	http://pqdd.sinica.edu.tw/twdaoapp/servlet/advanced?query=10253546
ISBN:	9781369602890

Impact of petrophysical properties on hydraulic fracture analysis.
Seals, Kelsey L.

Impact of petrophysical properties on hydraulic fracture analysis. - Ann Arbor : ProQuest Dissertations & Theses, 2017 - 172 p.

Source: Masters Abstracts International, Volume: 56-03.

Thesis (M.S.)--New Mexico Institute of Mining and Technology, 2017.

Hydraulic fracturing is the most common stimulation method used in medium- to low-permeability and unconventional reservoirs. A successful stimulation can increase the rate of return (ROI), ultimate recovery, and overall productivity over the life of the well, while an unsuccessful or poorly-designed stimulation can have the opposite effect, resulting in potentially severe economic losses. Accurate hydraulic fracture modeling requires extensive knowledge of reservoir rock data, including permeability, porosity, and mechanical properties, and identification of water-productive zones and lithologic barriers.

ISBN: 9781369602890Subjects--Topical Terms:

566616
Petroleum engineering.

Impact of petrophysical properties on hydraulic fracture analysis.
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100 1 $a Seals, Kelsey L. $3 3341890
245 1 0 $a Impact of petrophysical properties on hydraulic fracture analysis.
260 1 $a Ann Arbor : $b ProQuest Dissertations & Theses, $c 2017
300 $a 172 p.
500 $a Source: Masters Abstracts International, Volume: 56-03.
500 $a Adviser: Tom W. Engler.
502 $a Thesis (M.S.)--New Mexico Institute of Mining and Technology, 2017.
520 $a Hydraulic fracturing is the most common stimulation method used in medium- to low-permeability and unconventional reservoirs. A successful stimulation can increase the rate of return (ROI), ultimate recovery, and overall productivity over the life of the well, while an unsuccessful or poorly-designed stimulation can have the opposite effect, resulting in potentially severe economic losses. Accurate hydraulic fracture modeling requires extensive knowledge of reservoir rock data, including permeability, porosity, and mechanical properties, and identification of water-productive zones and lithologic barriers.
520 $a The objective of this work is to determine if using detailed petrophysical properties provides fracture design parameters that better represent the actual fracture behavior and subsequent well performance. The Nash Unit #23 well was selected as the case-study well, and is located in the Nash Draw field in southeast New Mexico. The well was drilled and completed in the lower Brushy Canyon Member of the Delaware Mountain Group (Guadalupian). The lower Brushy Canyon Formation in the Nash Draw field is vertically complex, lithologically heterogeneous and water-saturated, and requires especially detailed models for accurate simulations and analysis of hydraulic fracture behavior.
520 $a Completion treatment data from the Nash Unit #23 well was used to model the fracture behavior using Fracpro(c) software. The models were designed to simulate the differences in simplified input parameters against detailed input parameters, but were also designed to show how variations in layer resolution (detailed layers vs. lumped or averaged layers) affect the simulation results. Single Lithology, 10-ft, 5-ft, 2-ft, and 1-ft layer resolutions were created. The Single Lithology model is the most simplified lithologically and the 1-ft model has the highest layer resolution and petrophysical detail. For each layer resolution, an "Actual Values model" and "Default Values model" were created. The Actual Values models were designed with detailed, log- and test-derived data, and the Default Values models utilized Fracpro(c) software-derived data. The detailed petrophysical (reservoir and mechanical) properties data was obtained from using a variety of sources, including a mechanical log (sonic log), point load tests, core descriptions, core analysis, and traditional (gamma-ray, neutron-density) logs. Each model was simulated using the Nash Unit #23 treatment data in the Fracture Analysis mode. Resulting fracture parameter variables include average fracture width, fracture and propped half-length, and total fracture and propped height.
520 $a The simulated reservoir and fracture parameters were exported from Fracture Analysis mode simulations into Production Analysis mode in order to validate the fracture simulation models. The detailed and simplified fracture models effects on well production were analyzed. Results from both fracture analysis and production analysis consistently indicate that using actual values yields more accurate simulation results, and thus better represent the actual fracture behavior in a frac treatment. Use of software-default petrophysical values and over-simplified reservoir layer models yield significantly over- and under-estimated fracture behavior variables. These findings are confirmed by the production history matching results. Although a somewhat reasonable pressure match was achieved for the 1-ft Model, albeit with artificially inflated input fluid rates, the Fracpro(c) single-phase, single-flow 2D reservoir model is insufficient and limited in its ability to accurately simulate and predict the production behavior of wells with hydraulic fracture treatments producing from lithologically and vertically heterogeneous reservoirs. The 2D reservoir production simulation model is useful for rapid estimation or evaluation of the resultant production behavior of a well post-hydraulic fracture treatment. It is recommended that a 3D reservoir model be used for modeling and evaluating complex reservoir production behavior and history matching. Utilizing detailed and comprehensive petrophysical data while properly accounting for lithologic and layer detail effectively and accurately models multi-layered, vertically complex reservoirs in hydraulic fracture simulations and the well's subsequent production performance.
590 $a School code: 0295.
650 4 $a Petroleum engineering. $3 566616
650 4 $a Petroleum geology. $3 3173827
690 $a 0765
690 $a 0583
710 2 $a New Mexico Institute of Mining and Technology. $b Chemical and Petroleum Engineering. $3 3341891
773 0 $t Masters Abstracts International $g 56-03(E).
790 $a 0295
791 $a M.S.
792 $a 2017
793 $a English
856 4 0 $u http://pqdd.sinica.edu.tw/twdaoapp/servlet/advanced?query=10253546