Review of the Completion Practices in the Morrow Formation in Eddy, Chaves and Lea Counties of Southeast New Mexico

Pai, V.; Garbis, S.

doi:10.2118/11335-ms

Cited by 9 publications

(7 citation statements)

References 3 publications

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“…In the recent past, several papers [1][2][3][4][5][6][7][8][9] have been written about stimulation practices in the SENM Morrow. These formations of Pennsylvanian age are deposited erratically on the Northwest Shelf of the Delaware Basin, with the most prolific hydrocarbon bearing region lying largely in the Southeastern part of Chaves County, Western part of Lea County and the remaining occupying most of the Eddy County, as shown by the shaded region of Fig.…”

Section: Introductionmentioning

confidence: 99%

Fracture Stimulation Utilizing a Viscoelastic-Surfactant-Based System in the Morrow Sands in Southeast New Mexico

Pandey¹,

Itibrout²,

Adams³

et al. 2007

Proceedings of International Symposium on Oilfield Chemistry

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fax 01-972-952-9435. AbstractThis paper discusses the selection criteria, design methodology, and analysis of hydraulic fracturing treatments pumped using a solids-free, liquid CO 2 foam-based viscoelastic surfactant (VES) fluid system in Morrow Sand reservoirs located in Southeast New Mexico (SENM).The wells discussed in the paper were completed in various Morrow Sand intervals around 10,500 ft with an average Bottom Hole Static Temperature (BHST) of 190 o F. Wellbore completion constraints combined with reservoir parameters inclusive of low-pressured water sensitive formations, high rock Youngs' Modulus and unpredictable occurrence of water-bearing zones, lead to the selection of foamed VES fluids. This technology was successfully applied in the Morrow Sands in Eddy County of SENM. Fracture geometry analysis using surface treating pressures, radioactive tracers and production data, showed height growth containment and longer effective fracture half-lengths. Results also indicated successful stimulation past the cement squeezed intervals and temporary liner tie-backs run in to overcome lower pressure constraints. Finally, lower friction pressures helped in designing economical fracture stimulations for mature wellbores thereby generating an opportunity to recover otherwise bypassed hydrocarbon reserves.

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Section: Introductionmentioning

confidence: 99%

Fracture Stimulation Utilizing a Viscoelastic-Surfactant-Based System in the Morrow Sands in Southeast New Mexico

Pandey¹,

Itibrout²,

Adams³

et al. 2007

Proceedings of International Symposium on Oilfield Chemistry

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“…The literature pertaining to stimulation of southeastern New Mexico Morrow reservoirs is extensive 1,2,3,4,5,6,7,8 . Observations related to stimulation process are abundant, but there is a distinct shortage of guidance pertaining to maximization of NPV by optimizing treatment sizing in this formation.…”

Section: Introductionmentioning

confidence: 99%

Utilizing Flowing Pressure-Transient and Mass-Balance Analysis of SENM Morrow Producers To Calibrate 3D Hydraulic-Fracture Modeling – A Case History

Walser¹

2005

SPE Production Operations Symposium

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractSizing of hydraulic fracturing treatments in the Southeastern New Mexico (SENM) Morrow has historically relied on a trial-and error process whereby a three-dimensional fracturing model was built and run with simple gamma ray and compensated neutron density logs. Stress tables have been built utilizing over-simplified correlations involving conversions from gamma ray readings and effective porosity. The resulting simulated fracture-half lengths have been utilized in NPV (Net Present Value) optimizations to arrive at a final sizing decision.A study of a variety of existing Morrow producers was undertaken to determine whether or not flowing pressure transient analysis of existing properties could be utilized to "calibrate" three-dimensional fracturing models, so that future projects would better reflect fracture geometries that were more realistic than current practice.Results of the study are presented, and a practical, user-friendly model is demonstrated whereby flowing transient analysis may be utilized to adjust three-dimensional fracturing simulations as appropriate for optimizing stimulation NPV.

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“…Once a well no longer produced naturally at economically acceptable levels, it was considered for fracture stimulation. 2 They found a high volume of kaolinite and concluded that the observed water sensitivity was due to particle migration. An unfortunate side effect of this logic was that most Morrow fracture jobs were applied to wells that were marginal at best.…”

Section: Introductionmentioning

confidence: 99%

Improving the Success of Morrow Stimulations the Old-Fashioned Way

Logan

Gordon

Mathis³

et al. 2001

SPE Production and Operations Symposium

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TX 75083-3836, U.S.A., fax 01-972-952-9435. ___________________________________________________________________________ AbstractThe Morrow gas sand reservoirs in southeast New Mexico have permeability values that can range across three orders of magnitude. The best wells are completed naturally; the poorer quality rock usually needs to be fracture stimulated to produce commercially. Early attempts to fracture stimulate the Morrow with water-base systems were only marginally successful. Previous studies have suggested that the poor fracturing response to water-base systems was due to a combination of water-sensitive clays and capillary pressure effects. Early theories were that the Morrow experienced reduced permeability as a result of clay swelling and high water saturations in the zones invaded by fracture fluid filtrate. These issues were addressed by using energized fracture treatments that included high quantities of CO 2 and methanol in the fracture fluid. Stimulation success with foams has not been consistent. Successful fracturing response to smaller hydraulic fracture jobs using foams has been observed in higher permeability wells where near-wellbore damage has been successfully bypassed. However, in lower permeability wells where fracture length is critical to stimulation success, foams have not provided economic stimulation results.Although foams were used to address water-sensitivity issues, undesirable side effects countered the foam benefits. Low viscosities, high friction pressures and high chemical cost resulted in increased screenout frequency and increased treatment cost.Early screenouts with low proppant concentrations have left many Morrow reservoirs producing at rates well below their potential. To achieve optimum inflow potential, a fluid system is required that is capable of developing adequate hydraulic width and transporting larger volumes and concentrations of proppant.Water-base fracturing fluid technology has come a long way since the early days of Morrow fracture stimulation. Advances in both fluid selection and fracture design now make it possible to use a water-base system to achieve successful stimulation results in the Morrow in southeast New Mexico. The net result of this engineering approach is improved stimulation results with lower treatment cost. Two examples of successful applications of modern fracturing techniques demonstrate that operators in the Morrow of southeast New Mexico have a choice of fracturing fluids other than CO2 foams.

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Review of the Completion Practices in the Morrow Formation in Eddy, Chaves and Lea Counties of Southeast New Mexico

Cited by 9 publications

References 3 publications

Fracture Stimulation Utilizing a Viscoelastic-Surfactant-Based System in the Morrow Sands in Southeast New Mexico

Fracture Stimulation Utilizing a Viscoelastic-Surfactant-Based System in the Morrow Sands in Southeast New Mexico

Utilizing Flowing Pressure-Transient and Mass-Balance Analysis of SENM Morrow Producers To Calibrate 3D Hydraulic-Fracture Modeling – A Case History

Improving the Success of Morrow Stimulations the Old-Fashioned Way

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