1- Selección de Arenas Resinadas

8/11/2019 1- Seleccin de Arenas Resinadas

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ORDERING ANDDISTRIBUTION

SANTROL OVERVIEW

SELECTION ANDFIELD GUIDES

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Santrol

ResinCoatedProppant

SelectionGuide

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Curable

Selectio

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C

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Product Mesh Size Description Usage Temp. Range Approx. Closure

PREMIUM CURABLE PRODUCTS

HyperProp 20/40 Encapsulated curable , High Temperature/Closure


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Tem

pered

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lection

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NOTES:1. Santrol's Curable and Tempered LC, DC, HS and OptiProp coatings are available on ceramics and bauxite.2. All 20/40 products, except Tempered TF and Super TF, are premium mesh higher conductivity sands.3. All Santrol sand-based products are based on "Northern White" sands unless requested by the customer otherwise.

Product Mesh Size Description Usage Temp. Range Approx. Closure

PREMIUM TEMPERED (P RECURED) PRODUCTS

EconoFlex 20/40 High Strength Tempered High strength, l ightwe ight


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The following factors should be used as guidelines to help gather the pertinent information that will aid in the selection of the appropriate

proppant(s) for the application. Not all of the points will be applicable to every situation or able to be answered prior to running a modelsimulation. However, when the appropriate factors have been considered, the goal(s) of the treatment defined, and proper modeling

performed; an informed proppant selection can be made.

1. GOAL(S) OF THE TREATMENTOvercome near wellbore damage, in-depth fracture stimulation, near wellbore and/or perforation tunnel stabilization, prevent fines

and/or proppant production, reduce bottom hole producing pressure during draw down, allow increased production of viscous crudes,

increased injectivity into a formation, or combinations thereof.

2. TYP E OF ST IMUL ATION TR EATMENT TO BE PE RF ORME DFrac, Gravel Pack, Frac & Pack, Frac Pack, or Puddle Pack

3. TYP E OF WE LL AND PR ODUCTION (OR INJECTION) FLOW REGIMEDry gas or gas well with >10 bbl/day of water production? Oil well, oil & gas well, or oil, gas, & water production? Pressure maintained

reservoir under water flood, gas reinjection, CO2 flood or injection, steam flood or injection, or huff & puff?

4. MAX IMUM EF FECT IVE CLOS UR E ANTICI PATE D DURI NG THE LIFE OF THE WELLConsider: Bottom hole frac pressure, current reservoir pressure & reservoir pressure for abandonment of the zone.

5. FORMATION PROPERTIESConsider: Depth (TVD), bottom hole static temperature, effective formation permeability, Youngs Modulus, formation fine size and mesh

distribution, and proppant embedment in the fracture face.

Santrol Proppant Selection GuideFactors Affecting Proppant Selection

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6. WELLBORE TYPE, GEOMETRY, AND PERFORATION SCHEME

Type: Open hole, shot hole, cemented casing with perforations, slotted liner, or previous gravel pack completion.

Geometry: Vertical wellbore, high angle wellbore with ? degrees of inclination, extended reach, or horizontal wellbore perpendicular or

parallel to principal stresses; length of zone(s) to be treated.

Perforation scheme & type: Select fire limited entry, number of shots per foot with ? degrees phasing, high density phased, by casing

gun or tubing conveyed; or slots cut by abrasion jet tool. Size and depth of penetration?

7. ANTICIPATED PROPPANT CONCENTRATION TO BE PLACEDLow = < 1 lb/ft 2, Moderate = 1- 2 lb/ft2, High = 2-20 lb/ft2.

8. EFFECTIVE DOWNHOLE RATE, ANTICIPATED WIDTH, PROP TRANSPORT CAPABILITY BASED ON THE TYPE OF FLUIDThe type of fluid, effective downhole rate, and prop transport characteristics of the fluid(s) used can influence the type, density, and

mesh size of proppant to be used.

9. ECONOMICS ANDNET PRESENTVAL UEThe overall economics of a treatment and net present value of a well after the treatment should be optimized through modeling. The

choice of proppant can seriously affect the net present value of the well, rate of return on investment, ultimate recoverable reserves,and in some cases the viability of a project.

10. OTHERINFLUENCINGFACTORSSteam injection, hot-wet crushing at high temperature, mud (HCl-HF) acid used in sandstone acidizing, cyclic loading, and some

workover fluids/ solvent combinations can affect the longevity of certain proppants and should be given consideration pri or to placement

for the life of the well.

Santrol Proppant Selection GuideFactors Affecting Proppant Selection (Contd)


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Santrol Field GuideField Guide for Hydraulic Fracturing Proppants

FIELDDELIVERYProper care and handling of proppants is required to assure that the highest quality product is

available for the hydraulic fracturing treatment. Care in handling starts when the pneumatic trucks

are loaded with proppant. Listed below are recommended procedures that help assure delivery of

quality proppant for the job.

TRUCKINSPECTION

1. Trucks should be visually inspected to ensure that the inside of the trailer is dry and free of

contaminants.

2. Drop all bottom flanges on trailers to check tank bottoms for contaminants. In addition, all

belly line caps should be pulled and inspected.

3. Tanks and lines should be pressurized and blown through to ensure they are clean and empty

prior to arriving at the load out point.

4. All discharge hoses should be cleaned out and checked for a good seal with the coupling.

5. A coarse screen should be placed over the load hatch opening to catch any contaminants or

foreign objects that may enter the truck.

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Santrol Field GuideField Guide for Hydraulic Fracturing Proppants (Contd)

DELIVERY ON-SITE1. Once on-site prior to initial product discharge, the field storage bins and conveyor bins should

be checked for residual incompatible proppant that may have been left over from previous frac jobs.

Should incompatible proppant be present, this should be swept out or emptied and stored or

disposed of appropriately.

2. Pneumatic trucks should be unloaded at the minimum pressure to ensure a steady stream of

flow in to the receiving storage bin. This will be no more than 5 to 8 psi. Proppant entering the

field storage bin should, if possible, be directed at proppant already in the bin, and should never

directly impinge or strike metal walls at a high angle. Both high discharge pressures and impinging

on metal walls will cause both resin coated raw frac sand to degrade causing dust and excess fines

which will alter the performance of the base proppant.

3. Samples to be taken according to procedure recommended by API RP-56, as required, or may

be sent with the t rucks if caught properly during loading.


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Santrol Field GuideField Frac Job Procedures

1. FLUIDTESTINGPre-frac tests of fluids and (Resin Coated Proppants) RCP are recommended. Test the RCP at the highest design proppant

concentration. The main parameters to check for are viscosity retention and crosslink times. Adjustments to the pH of the fluid

and the amount of crosslinker and breaker adjustment may be required.

If chemical bonding agents are needed for low temperature bonding (see ACTIVATORS) or, if any other chemical additive is

used, they should be checked in the recommended concentration range to assure compatibility. When using persulfate breakers

in low temperature wells (< 200 F), additional breaker may be required.

2. SIEVEANALYSIS

RCPs are tested similarly to raw sands and RP 56 covers in detail the procedures needed for raw sand testing. A word of

caution is needed however as RCPs by their very nature are coated with a resin which will, over extended use, impart a resin

dust to the sieve weave. Caution is required to keep the sieves clean and not blinded. A gentle application of acetone will

usually be sufficient to clean the screens of resin dust. Ultra-sonic cleaning should then be used periodically.

3. CRUSHTESTSThese are carried out in the same manner for sand, ceramics or RCPs as specified in API recommendations. One note to

remember for RCP is that temperature and closure cause consolidation of particles and increase crush resistance while

eliminating free fines.

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Santrol Field GuideField Frac Job Procedures (Contd)

4. COLORVARIATION

Various RCP product grades and even the same product may have slightly different color variations due to both the underlying

substrate and different resins used in manufacturing. Northern sands of the St. Peter (Ottawa) type tend to be whiter than the

Jordan sands which in turn are whiter than the generally brown sands from Texas and Arizona. Santrol products are based on

high quality northern sands except where specified.

Color differences in RCPs do not affect the proppants ability to bond or perform as specified.

5. SURFACTANTS ANDADDITIVES

A surfactant should always be used wi th resin coated proppants to quickly and completely water wet the resin surface . Santrol

applies proprietary wetting agents to assist this process.

6. STATICCHARGE

RCP may have a static charge generated by either movement of the material or low humidity. Particles appear to stick to the

delivery belt from the field storage bins to the blenders. Grounding the delivery belt will reduce this charge. If static proves to

be problematical contact Santrol and anti-static agents can be added to the product.

7. CURABLE VERSUSTEMPEREDRCP (A QUICK FILED TEST)

Curable resin coated proppants bond together with temperature and a quick demonstration will show this effect.

Fill a metal spoon or a small piece of foil with the RCP. Hold the spoon or foil with an insulated cloth and heat with a butane

lighter until the color of the RCP darkens slightly. Curable RCP will bond together in a minute or less. Precured or tempered

product will not change color noticeably or bond together.

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Santrol Field GuideField Frac Job Procedures (Contd)

8. CONTROLLEDFLOWBACK

The important factor in bonding RCP is to get the bottom hole temperature back on the proppant as quickly as possible and to

force grain-to-grain contact of the proppant. By using a controlled flowback procedure, sometimes referred to as "forced

closure", closure and temperature return much quicker, allowing the proppant to be optimally placed in the fracture, ensure

bonding in place to prevent flowback, embedment and to provide high l ong term conductivity.

Adjustable chokes and gradual increases i n choke size during flowback are recommended.

9. BONDINGTIMES

RCPs bond together with a combination of temperature and pressure. In low temperatures an activator may be needed and the

section on ACTIVATORS shows estimated concentrations and shut in times for additives.

10. FOAM - FRACS WITHRCPS

By using a chemical activator in a foam frac system, wells can be flowed back within a four hour period or less. See the ACTIVATOR

section for the amount of activator recommended. When flowing back, make sure that the choke is as small as possible (i.e. 2/64,

4/64, 6/64). The choke size can be increased every four to six hours or as long as no sand is being produced.

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1- Selección de Arenas Resinadas

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