Real-Data On-Site Analysis of Hydraulic Fracturing Generates Optimum Procedures for Job Design and Execution

Johnson, D.E.; Wright, T.B.; Tambini, Mauro; Maroli, Renato; Cleary, M.P.

doi:10.2523/25920-ms

Cited by 12 publications

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“…This is one case where most/all of the problems associated with fracturing of low-permeability pay zones are present -as illustrated also in Figure 1 (b), adapted from an actual job executed recently, having failed to acquire (one major partner's) agreement for procedures needed to achieve pack-off (Refs. 16,17). However, in general, the successful fracturing of higherpermeability (thick) reservoirs pay-zones is not as difficult as for lower-permeability reservoirs; this may explain the success of most (including poorly rationalized) designs.…”

Section: Effects Of Permeability/variation On Fracture Growth and Pro...mentioning

confidence: 99%

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Critical Issues in Hydraulic Fracturing of High-Permeability Reservoirs

Cleary¹

1994

Proceedings of European Production Operations Conference and Exhibition

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The paper focuses on the sub-class of issues which can affect/dominate the performance of hydraulic fracturing in (gas or oil) reservoirs with higher-permeability, of order 1 mD (1Om D) or more in gas (oil) reservoirs. These issues are placed in the broader context of five major aspects which have been newly extracted from data-analysis over the past five years and which have greatly polarized/reversed industry thinking on hydraulic fracturing: heretofore, primary implications have been for lower-permeability reservoirs, where convection and tortuosity constraints impose a narrow (or nonexistent) window for successful design of fracture treatments, especially in light of properly-interpreted higher net fracturing pressures (than conventional industry models) induced by nonlinear rock response to (mul~iple) fractures. A much wider design window has made successful stimulation of higherpermeability reservoirs relatively easy and economically more rewarding, a result surprising to some. Perhaps more surprising are conclusions that appropriate proppant concentration may vary somewhat inversely with reservoir permeability and that fractures may preferentially grow (vs. initiate) in lowerpermeability strata/sections, the main theme of this paper. Fluid rheology also plays a much more important role in (leakoff behavior during) fracturing of high-permeability reservoirs vs. a lower-permeability role limited to near-wellbore (tortuosity) response. Some issues are illustrated with simulations performed by a unique computerized system, which allows credible matching of (treatments and production) data over a wide range of reservoir, fluid and job parametersthereby allowing establishment of conclusions with casehistories, supported by some careful laboratory experiments. With the aid of this computerized capability, dramatic results have been achieved in reducing job costs and improving production, especially for low-to medium-permeability reservoirs, but many of the implications can be carried over to high-permeability reservoirs.

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Section: Effects Of Permeability/variation On Fracture Growth and Pro...mentioning

confidence: 99%

“…Refs. 16,17) or the fracture must be contained in the pay-zone. However, the presumption of containment is rendered questionable by Issue No.…”

Section: Introductionmentioning

confidence: 99%

Critical Issues in Hydraulic Fracturing of High-Permeability Reservoirs

Cleary¹

1994

Proceedings of European Production Operations Conference and Exhibition

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Remediation of Production Loss Due to Proppant Flowback in Existing Wellbores

Nguyen

Stegent

Ingram

2006

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper presents the results of experimental study and field case histories of a remedial treatment technique using a lowviscosity consolidating agent placed into the propped fractures by coiled tubing (CT) or jointed pipe coupled with a pressure pulsing tool. The treatment fluids are designed to provide consolidation for previously placed proppant near the wellbore without damaging the permeability of the proppant pack. The consolidation treatment transforms the loosely packed proppant in the fractures and the formation sand close to the wellbore into cohesive, consolidated, yet highly permeable packs.Laboratory flow testing indicates that the proppant pack in a fracture model under closure stress required low-strength bonds between proppant grains to withstand high production flow rates. Field case histories are also presented to discuss treatment procedures, precautions, and recommendations for implementing the treatment process. One major advantage of this remedial treatment method is the ability to place the treatment fluid into the propped fractures, regardless of the number of perforation intervals and their lengths without mechanical isolation between the intervals. The fluid placement efficiency of this process makes remediation economically feasible, especially in wells with marginal reserves.

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Remediation of Production Loss Due to Proppant Flowback through Coiled-Tubing Intervention

Ingram

Nguyen

Hood³

2007

Production and Operations Symposium

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This presentation discusses the results of experimental and field case studies of a remedial treatment technique designed to eliminate fracture proppant production. This process uses a low-viscosity consolidating agent, which is placed into the propped fractures via coiled tubing or conventional tubing coupled with a pressure-pulsing tool. The treatment fluids are designed to provide consolidation for previously placed proppant near the wellbore without damaging the permeability of the proppant pack. The consolidation treatment transforms the loosely packed proppant in the fractures and the formation sand close to the wellbore into a cohesive, consolidated, yet highly permeable pack. Laboratory gas flow testing indicates that the proppant pack in a fracture model under closure stress required low-strength bonds between proppant grains to withstand high production flow rates. Field case histories are also presented to discuss treatment procedures, precautions, and recommendations for implementing the treatment process. One major advantage of this new remedial treatment technique is the ability to place the treatment fluid into the propped fractures, regardless of the number of perforation intervals and their lengths, without mechanical isolation between the intervals. The fluid placement efficiency of this process makes remediation economically feasible, especially in wells with marginally economic reserves. Introduction Many fracture-stimulated wells in the world today are subjected to curtailed production rates because of sustained proppant flowback problems. In fact, many wells are actually shut in because operators found them to be uneconomical to produce at subsequently lowered rates. Typically, production becomes restricted, such as by perforations being covered with produced proppant. The proppant produced during production often causes damage to downhole pumps and to surface equipment. In addition, repairing the equipment often results in costly downtime for the wells. Low production rates directly affect potential revenue for the operator. Frequent workovers required for cleanup or sand removal, including shut-in time, also factor into the revenue losses caused by proppant flowback or sand infill. However, the problem will return and the loss of revenue will continue unless a treatment can be found that will remediate the problem at its source and not simply clean up the wellbore. After an initial completion, it is often very difficult to conduct cost-effective remedial treatments to overcome proppant-production problems. Conventional remedial treatments are usually inadequate without some type of mechanical isolation technique. Conventional methods with a good chance of effective treatment are usually either too risky for well problems or too costly to consider for low-return reservoir conditions (or both). Resin materials have also been applied to treat proppant flowback. However, a key problem with using these materials has been the inability to achieve a uniform placement of the resin into propped fractures for the entire perforated interval. This problem is amplified by the presence of variable permeability, perforation debris, formation damage in the near-wellbore region, and the high viscosity of many resin materials. A system that attacks the problem at its source is a better approach to this problem. Using a system of treatment fluids placed precisely into propped fractures by coiled tubing can turn many marginal wells into excellent producers, and do so cost-effectively. The treatment chemicals introduced into the propped fracture will form a consolidated, highly permeable pack that can withstand the high drawdown associated with production. This paper discusses such a system.

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Real-Data On-Site Analysis of Hydraulic Fracturing Generates Optimum Procedures for Job Design and Execution

Cited by 12 publications

References 0 publications

Critical Issues in Hydraulic Fracturing of High-Permeability Reservoirs

Critical Issues in Hydraulic Fracturing of High-Permeability Reservoirs

Remediation of Production Loss Due to Proppant Flowback in Existing Wellbores

Remediation of Production Loss Due to Proppant Flowback through Coiled-Tubing Intervention

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