DX PHPA
Viscosifier
/ Shale Stabilizer / Water Treatment Flocculant
Description
Drilling Fluids
DX-PHPA drilling fluid additive is designed to be extremely effective in stabilizing sloughing shales, providing viscosity and filtration control, and producing reduced torque and drag in fresh water and KCl drilling fluids. High viscosity is achieved with low polymer concentrations.
Water Treatment
DX-PHPA is used for the clarification of industrial waste waters and surface waters, as well as for sludge conditioning. The use of this flocculant ensures high clarity of the treated water, effective activity also at low dosage, remarkable increase of the sedimentation rate and the possibility to operate within a wide pH range (from 4 to 13).
Typical Properties
Appearance
White free flowing powder
Charge
30% Anionic
Molecular Weight
>15 Million>
pH, 0.5% solution
7.0
Advantages
Enhances drilling fluid viscosity
Protects water sensitive sloughing shales
Minimizes problems near the well bore
Reduces torque and drag
Reduces or eliminates bit balling
Clarifies waste waters
Increases sedimentation rates
Rheology
To achieve good hole cleaning and fluid shear-thinning properties, maintain a PV:YP ratio of 1:1 to 1:2. If additional viscosity is desired, use 0.75 lb/bbl of polymer.
Also 4-6 lb/bbl of pre-hydrated bentonite can be added to supplement to viscosity but the viscosity will build as drilled solids are incorporated into the system.
Attention is focused on effective solids control, polymer concentrations and proper additions of KCl.
Solids Control
As with any fluid, drilled solids content should be kept to a minimum. Initial breakover to the system with DX PHPA may blind the shaker screens due to initial high viscosities. Once the polymer fluid is sheared, screen blinding problems are minimal. Usually 1-2 circulations are required.
Thermal Stability
DX PHPA polymer is thermally stable to 300ºF (150ºC) and has used successfully in wells with bottom hole temperatures in excess of 350ºF (175ºC). DX PHPA should be added to the system very slowly, with a funnel, at a rate of 30-45 minutes per bag.
Treatment of
Contaminants
Maintain calcium ion
concentration (Ca+2) below 400 ppm with soda ash, but leave 100
ppm Ca+2 in the system to prevent CO2 ion-blocking polymer absorption
on the shale. Use lime with discretion to maintain Ca+2 in system.
Dump excessive green
cement into the reserve pit.
Never add phosphates
to the system as this will have an effect similar to that of a
strong thinner such as chrome lignosulfonate.
Do not use chrome
or zinc compounds in the system.
Control hydrogen sulfide
(H2S) by increasing mud weight and adding zinc carbonate.
Maintain pH at 8.5 to 10.5. Higher pH levels are detrimental to polymer
absorption on shales.
Usage Levels
Maintain 0.25 to 0.75 lb/bbl of DX PHPA additive in the drilling fluid. Flocculation of drilled solids can occur at concentrations of polymer below these levels. This can be offset by shear and additional polymer.
Packaging
DX PHPA is packaged in 55 lb (25 kg) net weight bags or supersaks of
either 1110 lb or 1654 lb net weight.
Note
The information and data herein are believed to be accurate and have been compiled from sources believed to be reliable. It is
offered for your consideration, investigation and verification. Buyer assumes all risk of use. DX Oilfield Products, LLC will not be
liable for claims relating to any party’s use of our reliance on information and data contained herein regardless of whether it is
claimed that the information or data are inaccurate, incomplete or otherwise misleading.
Revised: 03.01.2015
DX Oilfield Products, LLC, 300 Jackson Hill Street, Houston, Texas 77007
