A comparison of hydraulic fracture performance during the initial development of the Moxa Arch Frontier sandstone in southwestern Wyoming (1975Wyoming ( to 1985 through infill development in 1989 to 1991 (320-acre spacing) and 1992 (160-acre spacing) is presented. The evaluation includes 3D hydraulic fracture modeling of reflected bottomhole pressures measured on 36 wells completed in 1992. In addition, in-situ stress test results from two wells are integrated with 3D fracture modeling and reservoir simulation of postfracture well performance to evaluate the evolution of fracture treatments over 17 years of development.The results from over 200 fracturing treatments were used to quantify the effect of treating fluid and proppant type on well performance. Detailed 3D fracture modeling illustrates the effects of insitu stress and leakoff properties on fracture geometry. The results from 3D fracture modeling of 33 mini-fracs indicates vastly different fluid-loss behavior from well to well and a variation of in-situ stress within the Moxa Arch. The performance of 1992 infill wells stimulated with guar-based gels (borate and zirconium crosslinked) and sand is similar to initial development wells stimulated using guar-based crosslinked polymers and sand. However, 1989 to 1991 infill wells stimulated using CO 2 foam and intermediate-strength ceramic proppants (ISP) did not perform as well as the water-based fluids and sand treatments. Fracturing net pressure data are presented that illustrate excess pressures owing to "proppant effects" and breakdown of stress barriers during fracturing that occurs in many treatments.
Openhole completions are often selected as the preferred completion technique to provide high capacity, low skin completions. With the advances of Alternate Path ® Technology (APT), a full gravel pack can be realized under challenging well conditions to provide increased long-term reliability. One draw back to openhole gravel packs (OHGP) has always been the inability to isolate undesirable water or gas, whether it be during the initial completion or during the production lifecycle of the well. Numerous improvements have been made in recent years with openhole packers to provide zonal isolation in standalone screen applications. Unfortunately, not all formations can be successfully completed with standalone screens due to non-uniform sand grain sizes, high concentration of mobile fines, or low hole angle through the pay interval. To achieve the benefits of zonal isolation, operators have opted to either complete the well as a cased hole completion, extend the limits of standalone screens beyond generally accepted best practice guidelines, use expandable screens with isolation, or attempt to seal the openhole annulus with swellable materials after gravel packing. These options may not be optimal and can compromise the ultimate recovery potential of the well.
This paper was selectad for presentation by an SPE Program committee following review of information oontainad in an abatract submitted by the author(s), Contents of the paper, as presented, have not bean reviewed by the Society of Petroleum Engineam and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any position of the Sociity of Petroleum Engineers, its offk%rs, or mambara. Papera presentad at SPE meetings are subject to pubiiostion raviaw by Editorial Commitfaes of the Society of Petroleum Engineers. Permission to copy is restricted to an abstract of net mere then S00 words. Illuetratiins may not be copied. The abstract should contsin conspicuous acknowfadgmentof where snd by whom the paper is presented. Write Librarian, SPE, P.O. Sox SSSSS6, Richardson, TX 760SS-S6S6, U.S.A. Telex, 16S245 SPEUT. Abstract T1-:. ---..3..--:--l.. >.-.L --.:-! P.-ugm gas Iurmumms.I rns proceaare mcluaes me mml-rrac volume in the pad volume, decreasing mini-frac costs and job delays.
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