BAKER HUGHES INTEQ DRILLING FLUIDS REFERENCE MANUAL PDF

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Asia Pacific. Skin damage to the wellbore was inhibiting production in a 6-in. The operator previously made several unsuccessful attempts to remove the damage, including a single MICRO-WASH remediation after several attempts by competitors to jet the well with base oil and acid. The general feeling was that the jetted chemicals may not have migrated to the backside of the screens. To ensure better placement of the chemical with equal distribution across the screens, Baker Hughes suggested using the ISAP system.

The system consists of two inflatable elements with a section of straddle pipe in between. When straddling a joint of sand screen, the elements are inflated to form a seal. The chemical treatment is then injected between the two elements into the screen and allowed to soak and remove the debris. Baker Hughes performed a record 24 isolation treatments along the wellbore.

Based on the observed flow, the operator estimated that oil production was four times the level before the treatment and is planning further applications of MICRO-WASH chemical treatment in conjunction with the ISAP system on several damaged wells. Gulf Coast. The operator was concerned about running 5-in. A tight spot was encountered at 7, ft m while running the liner.

The operator was able to ream from that point to 7, ft m in one hour. Another tight spot was encountered at 7, ft m. Reaming continued for 10 more hours to 8, ft. With the liner shoe in the desired location, the hanger was set and the liner cemented. Benefits from the system included:. This production was achieved by drawing down the pressure on the tight Bakken shale formation, allowing additional oil to escape.

The well soon reached a stable production level of Latin America. The ROP for these sections were Medina Silva, operations and marketing representative Baker Hughes in Mexico. All other companies that drilled in the field used a minimum of two bits to drill that section, and none of them got a better rate of penetration than we did. Precise wellbore placement in an entire lateral section eliminated trips and minimized nonproductive time for an operator in the Eagle Ford Shale area of south Texas, saving multiple rig days.

Accurate formation evaluation data placed the wellbore in the zone of interest over the entire lateral section of 3, feet m. An interval of 5, ft m was drilled in Mathias Schlecht, vice president, Baker Hughes drilling systems, was featured in a nationally televised newscast on July 8 about steerable drilling systems technology being employed on the BP relief wells. Watch the video. For the first time, exploration and production companies have a full-service facility to treat all of the liquid and solids waste generated during drilling operations.

In addition, the Eco-Centre facility includes remote monitoring capabilities, allowing companies online access to track their waste streams and ensure environmental reporting compliance. View full story. Limited Resources Yield Maximum Impact. The first place award for the 75 th anniversary book entitled it to be submitted to the STC International Communications Competition. Connect with us. Geothermal Energy Expo Oct. To ensure that you continue receiving our emails, please add us to your address book or safe list.

We respect your right to privacy — view our policy Copyright Baker Hughes Incorporated. All rights reserved. You are authorized to copy, print and distribute this document, provided that its content remains unchanged and this notice is preserved.

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CROSS REFERENCE TO RELATED APPLICATIONS

This application is a continuation in part of U. Provisional Application Ser. The present invention relates to water-based drilling fluids used during petroleum recovery operations, and more particularly relates, in one embodiment, to using water-based drilling fluids containing additives to inhibit penetration of the borehole wall by the fluid. Drilling fluids used in the drilling of subterranean oil and gas wells as well as other drilling fluid applications and drilling procedures are known. The drilling fluid is expected to carry cuttings up from beneath the bit, transport them up the annulus, and allow their separation at the surface while at the same time the rotary bit is cooled and cleaned. A drilling mud is also intended to reduce friction between the drill string and the sides of the hole while maintaining the stability of uncased sections of the borehole. The drilling fluid is formulated to prevent unwanted influxes of formation fluids from permeable rocks penetrated and also often to form a thin, low permeability filter cake which temporarily seals pores, other openings and formations penetrated by the bit.

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