Crisman Annual Report 2009 - Harold Vance Department of ...

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Gas Shales – Geomechanics/Completions Introduction The Woodford shale gas is an ultra-low permeability reservoir (0.000001 md to 0.001 md). Commercial gas production is made possible by hydraulic fracture stimulation. Optimum hydraulic fracture treatment design needs to consider geomechanical principles in fracture initiation and propagation of multiple transverse fractures in horizontal wells. Often, Woodford shale reservoir development is achieved by drilling multiple parallel horizontal wells (on N-S azimuth), with approximately 600 ft spacing. Each treatment stage in a well is designed to create a stimulated volume, defined as the rock volume contacted by treatment fluid and proppant, which experiences a desired enhancement to permeability. For reservoir optimization, the collective network of stimulations should affect the maximum volume, with minimal (optimal) overlap of adjacent treatment stages. Objectives The problem has several related components: the selection of an appropriate perforation scheme–for open and cased hole–for initiating multiple fractures within a fracture stage and the determination of an optimum fracture treatment spacing for a 1000 ft section of a well using fracture mechanics models. The latter should consider the interaction between neighboring wells in generating a stimulated volume. In this research, we present a survey of state-of-theart practices with reference to the above issues to assist in selecting the best strategy for the Woodford shale reservoir. Approach In wells with low to medium permeability like Woodford’s, transverse fractures that extend sideways provide drainage for a larger area of the formation, experiencing a long-term production increase. A major concern in designing the perforation clusters for transverse fracturing design is the stressshadow effect. When a hydraulic fracture is opened, the resulting compression will increase the amount of minimum horizontal stress because of the net fracturing pressure existence. If this compressional stress is big enough, it can turn minimum horizontal stress into maximum horizontal stress, thus changing a transverse fracture into a longitudinal one. By reducing the number of clusters per stage, stress interference can be minimized, which will reduce the likelihood of having improper fracture propagation. However, this reduction will increase the number of stages per well, which means more completion costs. Therefore, the number of stages and the spacing between the perforation clusters are the result of optimization between the cost of having more stages and reducing the stress shadow effect. For our cemented horizontal wells, the best completion strategy is to limit the number of stages and stimulate two or three perforation clusters per stage. Accomplishments Our study on stress shadow shows that it becomes quite small at an offset distance equal to about two times the fracture height (2H). This minimum spacing (2H) is required to effectively minimize the conflicts between two transverse fractures. Also the perforation-cluster lengths should not be longer than four times the wellbore diameter. This is to prevent the creation of competing multiple fractures. Considering the fracture height of 250 ft to 280 ft for Woodford shale formation (Vulgamore et al., 2007), and a horizontal lateral diameter of 7 in, the best option will be to have three perforation clusters with maximum lengths of 2 ft that are stimulated in a single stage for each 1000 ft of horizontal lateral. To align perforations with the preferred fracture plane, they should be oriented 0°/180° phasing. The other alternative is 60° phasing when used in conjunction with an acid-soluble cement system. Both perforation strategies have shown to be effective (Ketter et al., 2008). CRISMAN INSTITUTE Project Information 1.1.18 Gas Shales – Geomechanics/Completions Contacts Ahmad Ghassemi 979.845.2206 ahmad.ghassemi@pe.tamu.edu Babak Akbarnejad Crisman Annual Report 2009 17
PRISE – Petroleum Resource Investigation Summary and Evaluation Introduction As conventional resources are depleted, unconventional gas resources (UGRs) are becoming increasingly important to the U.S and world energy supply. The volume of UGRs is generally unknown in most international basins. However, in 25 mature U.S. basins, UGRs have been produced for decades and are well characterized in the petroleum literature. The objective of this work was to develop a method for estimating technically recoverable UGRs in target, or exploratory, basins. The method was based on quantitative relations between known conventional and unconventional hydrocarbon resource types in mature U.S. basins. hydrocarbon resources are conventional oil and gas, and 90% are from unconventional resources. Significance PRISE may be used to estimate the volume of technically recoverable hydrocarbon resources in any basin worldwide and, hopefully, assist early economic and development planning. PRISE methodology for estimating UGRs should be further tested in diverse sedimentary basin types. Conventional is 0–9% greater 10/13/2009 than in previous calculation From Old, 2009 Objectives The primary objective of developing PRISE was to establish a methodology for estimating unconventional technically recoverable resources in basins with no, or very little, unconventional resource development or data. A second objective was to create a system the industry can use to better understand the potential of unconventional resources in the target basins around the world. Armed with such estimates and understanding, the industry can better justify its future development activities or, in some cases, change course. For this study, published resource information from the USGS, PGC, NPC, EIA, and GTI were used to quantify recoverable resources in seven North American basins. 1 Quantified Recoverable Resources – 7 N.A. Basins (Old, 2009). Accomplishments To develop the methodology to estimate resource volumes, we used data from the U.S. Geological Survey, Potential Gas Committee, Energy Information Administration, National Petroleum Council, and Gas Technology Institute to evaluate relations among hydrocarbon resource types in the Appalachian, Black Warrior, Greater Green River, Illinois, San Juan, Uinta-Piceance, and Wind River basins. PRISE can be used to predict technically recoverable UGRs for target basins, on the basis of their known conventional resources. Input data for PRISE are cumulative production, proved reserves, growth, and undiscovered resources. We use published data to compare cumulative technically recoverable resources for each basin. For the seven basins studied, we found that 10% of the recoverable Project Information 1.1.20 Continued Development of PRISE Contacts Stephen A. Holditch 979.845.2255 holditch@tamu.edu Walter B. Ayers 979.458.0721 walt.ayers@pe.tamu.edu Kun Cheng CRISMAN INSTITUTE 18 Crisman Annual Report 2009
Page 1 and 2: Harold Vance Department of Petroleu
Page 3 and 4: Issue 3, February 2010 Stephen A. H
Page 5 and 6: Combustion Assisted Gravity Drainag
Page 7 and 8: 6 Crisman Annual Report 2009
Page 9 and 10: Summary The Crisman Institute has t
Page 11 and 12: Membership History The Crisman Inst
Page 13 and 14: 12 Crisman Annual Report 2009
Page 15 and 16: An Advisory System for Selecting Dr
Page 17: A procedure to measure the viscosit
Page 21 and 22: Gas Shales Simulation and Productio
Page 23 and 24: Characterization of Rock Transport
Page 25 and 26: An Analytical Approach to Model Sha
Page 27 and 28: P90 P50 P10 Fig. 3. P10, P50 and P9
Page 29 and 30: Density distribution from heat tran
Page 31 and 32: Experimental and Simulation Modelin
Page 33 and 34: Fig. 1. Set up of displacement appa
Page 35 and 36: Study of Solvent-Based Emulsion Inj
Page 37 and 38: Investigation of Hybrid Steam-Solve
Page 39 and 40: Experimental Studies of Steam Injec
Page 41 and 42: Combustion Assisted Gravity Drainag
Page 43 and 44: Well Spacing and Infill Drilling in
Page 45 and 46: Experimental and Numerical Simulati
Page 47 and 48: Enhanced Oil Recovery of Viscous Oi
Page 49 and 50: Alternate Power and Energy Storage/
Page 51 and 52: Propagation of Induced Hydraulic Fr
Page 53 and 54: » Use forward modeling of wellbore
Page 55 and 56: Decision Matrix for Liquid Loading
Page 57 and 58: fractions involved, a detailed sens
Page 59 and 60: Transient Multiphase Sand Transport
Page 61 and 62: Carbonate Heterogeneity and Acid Fr
Page 63 and 64: Fracture Aperture Variation Caused
Page 65 and 66: that contained 12 wt% HCl showed th
Page 67 and 68: Evaluation of Polymer-Based In-Situ
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Modeling of Discrete Fracture Netwo
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Thermo-Poroelastic Finite Element A
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Measurement and Correlation of Gas
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The falling body viscometer is sele
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Fracture permeability (md) 12 10 8
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CO 2 Mobility Control using Cross-L
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(a) Standard EnKF for permeability
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Aquifer Management for CO 2 Sequest
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Bibliography List of Theses and Dis
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» Florence, Francois; Validation/E
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» Diyashev, Ildar; Problems of Flu
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» Freeman, C.M., Ilk, D., Moridis,
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and Catalyst. Paper presented at th
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Exhibition, San Antonio, Texas, 24-
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