Advanced Fracturing and Reservoir Description Techniques Improves Economics in 
Utah, Green River Formation Oil Project

Schubarth, S.K.; Yeager, R.R.; Murphy, D.W.

doi:10.2523/39777-ms

Proceedings of SPE Permian Basin Oil and Gas Recovery Conference 1998

DOI: 10.2523/39777-ms

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Advanced Fracturing and Reservoir Description Techniques Improves Economics in Utah, Green River Formation Oil Project

S.K. Schubarth

R.R. Yeager

D.W. Murphy³

Abstract: Cop!n'ioht 199S.Society&Petroleum Engineers,Inc. This paper ws~red fw wesents~~at the 19SS SPE Permian Seein 011and Gas Recwery~ference hdd in Midland,Texas, 23-26 Mati 1998. This paperwas selectedfw -tstion by an SPE Program-Ittee fdl~ng M* of information mntained in an abstrscl submittedby Me ati(s). Contents~the PSW, as -ted hsw n~* IWI* by tie SoddY of Pe@olwmEnglnaaraandare eubj@ 10 wrredim by the authqs).~e material, es Eented, dw @ neceeesrily raflecl any pmm r.dthe Sociely& PetroleumEngim, its~-t w mem… Show more

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New Petrophysical Process Improves Reservoir Optimization by Linking Stimulation Design, Reservoir Modeling, and Economic Evaluation

Kessler

Frisch

Hyden

et al. 2000

SPE/AAPG Western Regional Meeting

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractNuclear magnetic resonance (NMR) permeability combined with newly developed petrophysical analysis improves the candidate selection process for production-enhancement treatments such as matrix acidizing, acid fracturing, and traditional hydraulic proppant fracturing. The new petrophysical model allows automatic zoning based on log data such as permeability, stress contrasts, or lithology. The automatic zoning provides information for stimulation design, reservoir simulations, and economic forecasting.Traditional stress zoning, which has enabled widespread usage of 3D modeling for the design of stimulation treatments, is now enhanced by an accurate permeability profile and automatic zoning. NMR logging provides a continuous, highquality permeability that falls within the accuracy range required for 3D hydraulic-fracture design programs and reservoir simulators to predict production.Combining the stimulation design and productivity calculations allows the operator to select the ideal stimulation treatment for the highest return on investment. The automatic zoning enhances both the stimulation design and reservoir simulations with minimal time and effort, allowing the operator to determine the most economical production enhancement scenarios, such as treatment type and job size.Once the stimulation is performed, operators monitor the production rates and declines to enhance the process. Production data can lead to an improved NMR permeability by optimizing the permeability coefficients for area-specific permeability equations. The process is repeated for additional wells in the reservoir with the ultimate goal of optimizing the reservoir development.

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New Petrophysical Process Improves Reservoir Optimization by Linking Stimulation Design, Reservoir Modeling, and Economic Evaluation

Kessler

Frisch

Hyden

et al. 2000

SPE/AAPG Western Regional Meeting

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Maximizing Well Production with Unique Low Molecular Weight Frac Fluid

Peles

Wardlow

Cox

et al. 2002

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractEffective fracture length is the portion of the propped fracture that cleans up after hydraulic fracturing procedure and contributes to well productivity. Studies indicate that this effective length is often less than 10% of the total propped fracture length. A large portion of our fracture stimulation dollars are wasted! This paper presents a comparative well study performed in the Cement field in south central Oklahoma. Stimulation of the Springer Sands using hydraulic fracturing with conventional low polymer fluids was compared with the use of low molecular weight polymer fracturing fluid. The depth of the three Springer Sands (Cunningham, Britt, and Boatwright) ranges from 12,500 feet to 15,500 feet and have an average permeability range of 0.1 to 5.0 md. This evaluation includes several components.Well production history matching and pressure analyses are used to determine effective fracture length. Results of these analyses are compared with calculated values based on laboratory generated cleanup data for the two fluid systems. Flowback rate, pressure, accumulated volume, viscosity, and polymer content were collected following the fracture stimulation treatments.The fluid systems compared in this study are a conventional low polymer system with gel breakers and a new, low molecular weight polymer system that requires no breakers. Both fluids use borate cross-linking chemistry. The low molecular weight fluid system creates transient, high molecular weight polymer chains at higher pH conditions. After exposure to the formation minerals, the pH drops and it reverts to a clean, nearly Newtonian, low viscosity fluid that causes little conductivity damage.The results of this study show that the use of low molecular weight fracturing fluid provides significant improvements in the effective fracture length over conventional low polymer fracturing fluids. Simple engineering tools have also been developed to evaluate both fluid and proppant selection and job design to achieve improved well performance. It also demonstrated that improved recovery of the fracturing fluid can be achieved at excellent rates without the use of conventional gel breakers.

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Maximizing Effective Proppant Permeability under High-Stress, High Gas-Rate Conditions

Dusterhoft

Nguyen

Conway³

2004

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractWork reported in this paper shows that fracture-pack permeability and conductivity are impacted by the mobility of formation-generated fines plugging under high-stress and high gas flow-rate conditions. The authors examine two approaches to (1) prevent formation fines from entering the proppant pack and (2) provide higher sustained fracture-pack permeability and conductivity under severe production conditions. The paper further shows that significant improvements can be obtained in both the short term and the long term, and how these improvements can be used to provide sustained gas production.The results of laboratory testing are reviewed in detail, including the mechanisms by which fines are immobilized and the conductivity is maintained. The mechanisms involve an on-the-fly, direct coating of proppant with surfacemodification agents (SMA) just before the proppant is blended with the carrier fluid. The chemical properties of the SMA can be varied widely to meet downhole conditions and production flow rates. The treatment renders the formation sand and fines immobile so that migration and plugging do not occur. In addition to fines stabilization, SMA can be formulated using liquid resin to consolidate the proppant pack, making it useful in controlling proppant flowback at high production rates, and in providing long-term pack stability. The effects of non-darcy flow are also examined and compared to baseline data.Field studies are reviewed to evaluate how actual productivity can be affected, both short-term and long-term, by controlling fines damage to provide long-term fracture conductivity.

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Advanced Fracturing and Reservoir Description Techniques Improves Economics in Utah, Green River Formation Oil Project

Cited by 3 publications

References 0 publications

New Petrophysical Process Improves Reservoir Optimization by Linking Stimulation Design, Reservoir Modeling, and Economic Evaluation

New Petrophysical Process Improves Reservoir Optimization by Linking Stimulation Design, Reservoir Modeling, and Economic Evaluation

Maximizing Well Production with Unique Low Molecular Weight Frac Fluid

Maximizing Effective Proppant Permeability under High-Stress, High Gas-Rate Conditions

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