new technologies - gob.mx · 2019-05-14 · new antiscales chemicals series imp-esim • secondary...

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January, 2017

Instituto Mexicano del Petróleo(Mexican Petroleum Institute)

New Technologies




Three of the main problems that

currently exist in naturally fractured

carbonate reservoirs (NFCR) with high

temperature and salinity are, maintain

wells productivity, reduce operating

costs and increase the oil recovery

factor.

To solve such challenges it is necessary

to control the gas and/or water

channelization, alter the wettability of

the rock, reduce the interfacial tension

of the system brine-oil and avoid

damage to the formation due to the

presence of organic and inorganic

scales.

The foaming multifunctional agents of

IMP technology are the firsts of their kind,

they are patented worldwide and have the

capability to:

Generating stable foams under oil

reservoir conditions, this in order to

control undesirable fluids channelization.

Reduce the interfacial tension of the

brine-oil system and alter the wettability of

the rock, aiming to extract the

hydrocarbon retained in areas of low

conductivity.

Controlling the formation of mineral and

organic scales, with the purpose of avoid

damage to the formation.

Not create stable emulsions, this in order

to avoid damage to the formation and the

plugging problem in the production string.

Testing through processes Huff

and Puff in Pemex wells that had

had low oil and high gas

production, allowed to prove that

the multifunctional foaming agents

control the gas mobility and

increase oil production in the range

of 30 to 100%.

The new chemical process of

additional oil recovery has showed

that it has the ability to control the

formation damage problem that is

caused by organic and inorganic

scales and is marketed through the

brand new "IMP-WET - FOAM®" .

Laboratory tests performed with the

multifunctional foaming agents

have showed they can be used in

enhanced oil recovery processes

surfactant-polymer (SP) and

surfactant alternated with gas

(SAG).

1 Multifunctional foaming agents for additional oil recovery

Description Problems that are solved Application

Reduction of the interfacial tension of the brine-oil systemand alteration of the wettability of the rock

Multifunctional foaming agent

Channeling gas in

naturally fractured

carbonate reservoirs




Benefits obtained with the multifunctional foaming agent IMP-ESAT-2000 at the C-317 well belonging to Akal field of the Cantarell complex

Foaming lifetime: 15 months

Benefits on the production of oil obtained during 15 months

Foam

Before foam

Declination without foam

Throttle

Comparison period

Incremental

Additional

Bitter

june

Sludge pumps Sludge pumps

Bitter

April

Panther pumps

Crane Boat

October 2008

Re

sult

s

|D

ep

osi

t |

Flu

ids|

Inst

alla

tio

ns|

Tim

e

Requirements

Data published by PEMEX in 2012 (3 months trial)

days

Time (month/year)

Costs and benefits for the foam injection in the PEMEX well C-317




Description Problem

Mineral scales generation on either

the formation face or the production

rig due to water incompatibilities or to

the intrinsic nature of formation waters

containing high salinities and

hardnesses.

Reduction in the oil production and

increase of operation costs due to the

partial plugging of both the formation

face and the production rig.

Production rig corrosion.

Application

The IMP has a family of patented chemicals

which, under high temperature and ultrahigh

salinity, inhibit the growth and disperse

mineral scales generated by the

incompatibility among the injection water

(seawater) and the connate water in

secondary recovery processes.

The chemicals are commercialized under

the trademark series IMP-ESIM. They

tolerate temperatures up to 180 °C, salinities

as NaCl up to 400,000 ppm and total

hardnesses as CaCO3 up to 150,000 ppm.

The chemicals series IMP-ESIM is

compatible with both polymers and

multifunctional foaming agents, so it can be

used in formulations for enhanced-oil-

recovery-processes and production-

assurance applications.

Due to its versatility and high performance,

the chemicals series IMP-ESIM can be used

to control problems from scales in the

production rig and hydrocarbons-carrying

pipelines.

New antiscales chemicals series IMP-ESIM

• Secondary recovery processes.

• Enhanced oil recovery processes.

• Mineral scales control processes

in wells having high temperature,

high salinity and high water cuts.

Mineral scaling by incompatibility of waters at

163 ° C

Control of mineral scales on incompatible

water at 163 ° C

Conate water / Oil / rock

Adding sea water to the system

Scale Formation

Adding a solution to the system of IMP-ESIM-2000. The solution was prepared

with sea water

Dissolution of the scale




Description Problem

The producing gas wells, located in

mature fields, present contributions of

accumulations of liquids (brine and

condensate), resulting in a gradual

and progressive reduction of the

production of gas, due to partial

plugging that generates the loading of

liquids within the gas wells.

The presence of emulsions and

mineral scales increases the

challenge of expelling liquids in gas

wells, being able to reach to such

levels that lead to that the well has an

even behavior and stop the

production.

Application

The IMP has a patented family of foaming

multifunctional agents with the ability to

expel liquids in gas wells presenting high

water cuts and condensates production of

up to 20%.

The products are marketed under the brand

name IMP-AMES series and are

characterized by not generating emulsions,

tolerate brine with high salinity and

hardness, as well as by inhibit or disperse

mineral scales.

The synthesis process through which are

obtained the chemicals IMP-AMES series,

as well as their biodegradability quickly and

virtually no toxicity showed against

microorganisms such as Daphnia magna

and Artemia franciscana allows to establish

that they comply with the context of green

chemistry.

Multifunctional foaming agents for gas wells having liquid-loading problems

Technological tests carried out in

gas wells that have problems with

liquid-loading and which are

located in fields belonging to

PEMEX made it possible to

demonstrate that low dosages the

multifunctional foaming agents

have an excellent performance in

the expulsion of liquids and

increase the production of gas to

values according to the

expectations of the oil operator.

Level of liquids in gas well that presents

problems of liquid-loading (obtained with

echometer reads)

Aspectos de líquidos obtenidos

con IMP-AMES-3000-18 en un pozo de gas

Sin emulsión estable

Equipment used to evaluate the performance in

laboratory of multifunctional foaming agents

Aspects of liquid obtained with IMP-AMES-3000-18

in a gas well

Without stable emulsion

Compressed gas

Pressure regulator

Recycler of constant

temperature

DefocusColumn for

foam generation

CollectioncolumnDiffuser

foam

Brine

Co

nd

ense

d

Commercialproduct

Met

ers




The oil-wet nature of Mexican

carbonate reservoirs is

determined by asphaltene and

resins adsorption – deposition

Reduction of effective

permeability due to clogging of

flow channels by heavy

hydrocarbon deposits, as well as

the change of rock wettability

Precipitate asphaltenes in some

stage of the productive life of the

wells

Substitution of asphaltene

dispersants dissolved in xylene

Asphaltene dispersant –

wettability modifier for removing

and controlling formation

damage by asphaltene

deposition

A Huff & Puff test carried out

demonstrated the reduction on

the slope of production

declination (lost barrels per day)

Increment of daily oil production

2 New chemicals used for foam injection to improve oil recovery IMP-CDFIM-3000

Producin

g

formatio

n

Asphaltene

particle

Flow

channels

Before

IMP-CDFIM-3000

After

IMP-CDFIM-3000

- 4.0 + 0.6

+ 87

Reduction the slope of

production declination

Increment of daily

oil production

Description Problem Application




Depleted reservoirs and

hydrocarbon low production well

due to:

Hydrates formation

Lines freezing

Unstable flow and high pressure

drops in production tubing

Water production

Bottom well toll designed for an

specific production conditions, to

increase well productivity, extend

fluent life of wells and avoid lines

freezing

MPFV® Technology benefits:

•Control of gas and water

production

•Solve liquid loading in gas wells

•Avoid freezing in superficial

facilities

•Reservoir energy management

on unconventional systems

•Stable production

•Placed in downhole with help of

wire line unit

•MPFV® systems for different

sizes of tubing

MPFV® system, has been

installed successfully on 579

wells in México

Using the MPFV®, it is possible

to rise a 20% the average gas

production in each well and with

5 applications of this system

avoids drilling one new well. It

has great impact in reduction of

environmental risks also due the

reduction of water production

Installation of these devices has

been allowed:

•Increasing recovered production

of 151 millions scfd

•10,100 barrels per day of oil

3 Flow Pattern Enhancer System (MPFV®) in production control and reservoirs optimization





Flow Pattern Enhancer System (MPFV®) in production control and reservoirs optimization

The MPFV® has been applied in unconventional reservoirs to maintain oil production. In just one well of

an unconventional reservoir, the MPFV® system allowed an increase in the recovery of 4,653 oil barrels

in 154 days of continuous production

The last quality control is in field

MPFV® systems for different

sizes of tubing




4 Non-destructive pipeline-integrity, using surface electromagnetic inspection (TIEMS®)

Response for problems in the

pipeline transportation system:

Shared rights of way, with groups

of near and interconnected

pipelines with different paths, it

was impossible to inspect

pipelines with any other

technology

Pipeline leaks, with significant

annual economic impacts

Substitution of unsuitable

technologies for the conditions of

most pipelines, such as: Direct

Current Voltage Gradient,

Alternating Current, Voltage

Gradient, and Pipeline Current

Mapper

Technical limitations for

inspecting pipelines over 4 m of

depth

The EMPI (Electromagnetic

Pipeline Inspection) is a non-

destructive, surface technology

to assess quantitatively the

physical sate of the pipeline

coating. It does not require

diggings or interruption of the

operation in the pipeline and its

cathode protection system (CPS)

EMPI technology allows to:

• Identify and classify zones based on

the extent of the damage of the

pipeline coating

•Determine the geometric trajectory of

a single pipeline or group of pipelines

in plane view and at depth

•Estimate the performance of the

CPS

•Detect connections between

pipelines in operation with out-of-

service pipelines and other metallic

structures.

•Assess the subsoil corrosivity

The EMPI has been applied in

five areas in pipelines in the

South Region of Mexico

Improved planning maintenance

programs

Allows optimization of human,

material and financial resources

Allows:

•Accurate inspections in shared right

ways (nearby and interconnected

pipelines), river crossings, urban

areas and identification of the source

of anomalies

•Evaluation of pipelines up to 20 m

deep

•Quantitative and deterministic

evaluation with standardized and

formalized criteria.





Impact Field application: inspection of pipeline affected by microbial corrosion

Detailed inspectionRegional inspection

Microbial corrosion:

a) Because the coating is

not suitable for the current

pipeline temperature and

soil conditions.

b) Because the coating

shows permanent

damage from the

beginning.

c) Loss of external metal up

to 0.110 inches of depth.

With the EMPI is

possible to identify

the type of coating

In this pipeline, two

types of insulations

were identified, from

0+000 Km to 0+600

Km and from 1+600

Km to 560 Km

With the detailed

inspection, the exact

location of the

coating damage was

determined

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(4)

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lati

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ance

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ival

ent

ho

liday

are

a, d

/dx

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anomaly

Non-destructive pipeline-integrity, using surface electromagnetic

inspection (TIEMS®)




5 System for leak detection and illegal connections

Detect in real-time leaks and

illegal connections in pipelines

Non-intrusive and remote system to

detect in real-time leaks and illegal

connections, through combination of

different detection and localization

physical principles. The system sends

the final results to the SCADA system

Consists of the following subsystems:

•Balance calculation software based

on “SIMPORT” (IMP Simulator

pipeline operations in Real Time) for

the detection, localization and

determining of leaks volume

• IMP Acoustic Leak Detector, operates

using its own sensors in pumping

measuring stations, or sectioning

valves

•Optical fiber leak detector, operates

using fiber optic cable and own

sensors installed on the right of way.

The equipment cover the distance of

50 KM and detects events with a +/-5

meters accuracy

• Integrated data processing using

artificial intelligence methods to

reduce false alarms in the process of

monitoring ducts

The system can process and

analyze data to detect and locate

leaks and illegal connections to

monitoring subsystems and send

the final results to the SCADA

system.

There is no similar service in the

market





System for leak detection and illegal connections

Evidence of finding research located in

pipeline (between E. V. Teoloyucan and

E. V. Tepeji

Modulo de sensores: Geófono, termómetro,

acelerómetros.




Substitute film inhibitors products

to control corrosion problems

with no good results

The inhibitors used in pipelines

do not control uniform and

located corrosion problems

simultaneously, furthermore the

results are not constant

The increase in the production of

heavy crude oil and the greater

amount of pollutants increases

these aggressive corrosion

problems

Family of chemical compounds

(basics) with inhibition corrosion

properties named IMP-ALICIM

Allows to control and maintain

within specification, the speed of

corrosion in pipelines

Controls efficiently uniform and

located corrosion problems in

pipelines operating conditions

Do not generate emulsions and

are technically and economically

viable

A corrosion rate of 0.1

thousandths of an inch per year

(MPA) was obtained at points

evaluated with the IMP-ALICIM-

001 in field tests in 30” and 48”

pipelines. This compares

excellently with the value of 2.0

mpa of corrosion control

The corrosion rates prior to the

application of IMP corrosion

inhibitor ranged between 3.0 and

14 mpa out of maximum

specification (2.0 mpa)

The improvement in the

corrosion control increases the

pipeline reability

6 Corrosion control by new chemicals inhibitors IMP-ALICIM-001

Interior pipe cut with corrosion





Corrosion control by new chemicals inhibitors IMP-ALICIM-001

Comparative corrosion rates obtained with IMP-ALICIM-001

corrosion inhibitor in a 30” pipeline (Maya crude)

-2

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0 1 2 3 4 5 6 7 8

Ve

loci

dad

de

co

rro

sió

n,

mp

a

Meses

TRD D

Especificación (2.0 mpa)

Línea de Referencia

IMP-ALICIM-001

Histórico 2013

Jul Ago Sep Oct Nov EneDic Feb

Reference line

Corr

osio

n r

ate

, m

pa

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a

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IMP-ALICIM-001Especificación (2.0 mpa)

Histórico 2013

Jul Ago Sep Oct Nov EneDic Feb

Comparative corrosion rates obtained with the IMP-ALICIM-001

corrosion inhibitor in a 48” pipeline (Istmo crude).

Historical 2013

Corr

osio

n r

ate

, m

pa

Month




The production of hydrocarbons

is interrupted by the clogging of

the production lines, increasing

the maintenance of wells.

Incompatibility between injection

water (seawater, rich in sulfates)

and formation water (rich in

divalent cations Ca++)

Family of chemical compounds

with anti-fouling properties for

high salinities, high hardness and

high temperature (200,000 ppm

of total solids, hardness of

calcium carbonate of 50,000 ppm

and temperaturas of 150 °C):

This technology focuses on

managing efficiently the inorganic

incrustation: calcium carbonate,

calcium sulfate mainly.

IMP-ESIM-2000 is a sulfate and

calcium carbonate scales

inhibitor

highly effective to inhibit the

CaSO4 precipitation

7 New Antifouling chemicals ESIM-1000 and ESIM-2000


Precipitated criystals on pipe

walls

Whitout product

CaSO4 crystals

50 ppm IMP-ESIM-2000

Technological test demonstrated

reduction of inorganic scale of

CaSO4

http://www.google.com.mx/url?sa=i&rct=j&q=&esrc=s&frm=1&source=images&cd=&cad=rja&docid=Pp6RZ7rux-LT9M&tbnid=5dVuXx8Iq2s-6M:&ved=0CAUQjRw&url=http://halliburtonblog.com/flow-assurance-and-scale-challenges-in-mature-fields/&ei=K5dmUv_cOobj2wWGioGYDA&bvm=bv.55123115,d.b2I&psig=AFQjCNHOa_SE3lsDXVjJMrR1Tv-ITxxW0Q&ust=1382541476261997

http://www.google.com.mx/url?sa=i&rct=j&q=&esrc=s&frm=1&source=images&cd=&cad=rja&docid=Pp6RZ7rux-LT9M&tbnid=5dVuXx8Iq2s-6M:&ved=0CAUQjRw&url=http://halliburtonblog.com/flow-assurance-and-scale-challenges-in-mature-fields/&ei=K5dmUv_cOobj2wWGioGYDA&bvm=bv.55123115,d.b2I&psig=AFQjCNHOa_SE3lsDXVjJMrR1Tv-ITxxW0Q&ust=1382541476261997




Permeability prediction:

traditional techniques use total

porosity and don´t consider

pores connectivity

Characterization of

heterogeneous formation with

different porosity types (naturally

fractured reservoirs)

Improve petrophysical evaluation

with new methods using

conventional well logs

Methodology for petrophysical

inversion of carbonate formation that

uses conventional well logs

interpretation techniques to evaluate

correctly hydrocarbon volumes

New technology for lithological and

petrophysical evaluation for

conventional well logs. Evaluation of

total, vuggy and fractures porosity,

secondary porosity and effective

porosity. Allows:

•Determine initial oil saturation and

predict remaining oil saturation in

different pore systems

•Determine volumes of limestone,

dolomite and clay

•Separate and quantitatively

determine different porosity types:

matrix, fractures, and vuggy

•Evaluate connectivity of pore

systems and estimates fracture

porosity

•Determine elastic modules and

formation mechanical parameters

It was carried out in 90 Wells,

with the following results:

•Evaluate correctly hydrocarbon

volumes

•Improve the static

characterization of carbonated

reservoirs, porous space

microstructure and separate

porosities: matrix, fracture and

vuggy

This technology has been

applied successfully to evaluate

porosity of fractures, vuggy

porosity and connected porosity.

With this porosity distribution,

new models for water saturation

were developed to improve

original oil in place and reservoir

characterization models

8 Petrophysical inversion for dual porosity carbonates





Petrophysical evaluation for dual porosity carbonates

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7840

7800

7760

7720

7680

7640

7600

7560

7520

7480

7440

7400

7360

7320

7280

7240

7200

7160

7120

7080

7040

7000

6960

6920

6880

6840

6800

6760

6720

6680

6640

6600

6560

6520

6480

6440

6400

6360

6320

6280

6240

6200

6160

6120

6080

6040

6000

5960

5920

5880

5840

5800

5760

5720

5680

5640

5600

5560

5520

5480

5440

5400

5360

5320

5280

5240

5200

5160

5120

5080

5040

5000

4960

4920

4880

4840

4800

4760

4720

4680

4640

4600

4560

4520

4480

4440

4400

4360

4320

4280

4240

4200

4160

4120

4080

4040

4000

3960

3920

3880

3840

3800

3760

3720

3680

3640

3600

3560

3520

3480

3440

3400

3360

3320

3280

3240

3200

3160

3120

3080

3040

3000

2960

2920

2880

2840

2800

2760

2720

2680

2640

2600

2560

2520

2480

2440

2400

2360

2320

2280

2240

2200

2160

2120

2080

2040

2000

1960

1920

1880

1840

1800

1760

1720

1680

1640

1600

1560

1520

1480

1440

1400

1360

1320

1280

1240

1200

1160

1120

1080

1040

1000

960

920

880

840

800

760

720

680

640

600

560

520

480

440

400

360

320

280

240

200

160

120

80

40

0

BTP-KS

KM

< 0.001

0.001-0.01

0.01 - 0.05

0.05 - 0.1

0.1 - 0.5

0.5 - 2

2 - 20

20 - 100

> 100

Porosidad de matriz

Arcilla

Porosidad secundaria

Arcilla

Dolomía

Caliza

Porosidad de matriz

Porosidad secundaria

Porosidad de fractura

Porosidad secundaria conectada

Porosidad de mtariz-vúgulo

Porosidad de fracturaminimuma

Porosidad de fracturamaximuma

Porosidad de mtariz-vúgulo

21

16

11

6

CALI

errores

1.0

0.5

0.0

-0

.5

-1

.0PS1

0.3

0.2

0.1

0.0

0.1

0

0.0

5

0.0

0

0.8

0

0.6

0

0.4

0

0.2

0

0.0

0

-0

.20

Perc1

0.8

0

0.6

0

0.4

0

0.2

0

0.0

0

-0

.20

10

0

75

50

25

0

Gamma

12

0

10

0

80

60

40

20

DTP

10

00

0

10

00

10

0

10

1

MSFL/LLD

2.8

2.6

2.4

2.2

2.0

RHOB

0.4

0

0.2

5

0.1

0

-0

.05

Perc2

28

0

24

0

20

0

16

0

12

0

80

DTS

10

00

80

0

60

0

40

0

20

0

0

K, Mu

M438(1) 02.10.07

PS2

0.3

0.2

0.1

0.0

Inversión Petrofísica

Densidad de fracturasLitología Porosidad

43210 1.0

0

0.7

5

0.5

0

0.2

5

0.0

0

1.0

0

0.7

5

0.5

0

0.2

5

0.0

0

Intervalode variación(min / max)

Porosidad de fractura/Porosidad de matriz-vúgulo

versión básica

Matrix Porosity

Fracture Porosity

Lithology

Vuggy Porosity

Connected Porosity

Elastic Module

Well log

Results

So initial

So remaining

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

3845 3846 3847 3848 3849 3850 3851 3852 3853 3854 3855

Soi

Sor Comparative of So determined with Petrophysical

Evaluation (Green line – initial So, red line – remaining

So and cores data (red point)

Determination of remaining oil saturation

Permeability Distribution prediction




To improve the oil recovery factor in

low-permeability siliciclastic

reservoirs. To address this

challenge, a technology to enhance

the oil recovery factor by microbial

processes has been developed at

both laboratory and reservoir

scales. This technology has been

evaluated and proved its potential

application

To design a low-cost microbial

process to increase the oil recovery

factor

• Technological solution to

increase the oil recovery factor

• Biotechnological methodology

that improves hydrocarbon

recovery in low-permeability

porous media

• Promotes substantial changes in

the reservoir properties including:

oil viscosity, rock wettability, and

pressure. This is achieved by

microbial processes that produce

biomass and bioproducts

resulting in an improvement in

the oil flow from the reservoirs

Formulation and optimization of

cultivated media for growth and

production of fermenting microbes

to produce useful metabolites for

the recovery of hydrocarbons

At laboratory scale, an increase of

6.5 to 29.8% of hydrocarbon

recovery by microbial processes in

carbonate rocks and sandstones

has been reached utilizing different

crude oils

A recent field test was conducted in

a Tertiary siliciclastic reservoir

utilizing a Huff and Puff evaluation

process. An increase of total

production of 40-52% and an

increase of oil production of 22-

44% were obtained

9 IMP-RHVM®: Enhanced oil recovery by microbial processes

SEM image of anaerobic extremophiles bacteria. Microorganisms and nutrients well injection process

Unidad

biotecnológica

Ag

ua

Inyección

Metabolitos:

CO2, H2, ácidos, alcoholes, surfactantes

Melazas

Mejoramiento de la movilidad de aceite

Producción de aceite

So

lució

n d

e

mela

zas c

on

bacte

rias





10 In-situ gel for control conformance

Reduction of productive live wells

due to high formation water

production

Gel systems to control water

invasion in extreme temperature

(130 a 145°C) and salinity

conditions 120,000 - 254,000

ppm)

• GISATS-1000

• TERASAT-1000

• TERASAT -2000

This technology focuses on block

water advance in high fractional

flow natural fractured reservoir

The experimental results showed

gel formation stability in high

temperature (145 °C) and salinity

(254,000 ppm) conditions

Thermal stability was verified

over a 6 months period at 130 °C

and 120,000 ppm TDS

In solid state the polymer

presents stability above 300 °C

The gel and formation water from

wells with 93,000 and 84,000

ppm total solids were tested with

successful results

IMP-TERASAT-1000 @130°C and 120,000 ppm STD

“Commercial” Gel

Poliacrylamide + Cr3+

24 hrs @ 130°C y 120,000ppm STD

Polímero Imagen Polímero Imagen

35

37

36

38


6

27

9

33


6

27

9

33


IMP-GISATS-1000 @130°C and 120,000 ppm STD




11 HIDRO-IMP®: Process for upgrading of heavy crude oil and residues


• Catalytic hydrocracking at

moderate reaction conditions

• Reactors with selective

catalysts for:

Hydrodesmetallization

(HDM)

Hydrodesulfurization (HDS)

Hydrocracking (HDC)

• Moderate conversion of residue

to distillates (40%) and

increase of upgraded oil yield

(104-105 vol%)

• Low sediments formation

• High impurities removal (sulfur,

asphaltene, nitrogen, metals)

• Production of upgraded oil with

low acidity, corrosivity, viscosity,

and tendency to coke formation

• Low investment and operating

costs

Heavy oil with high metal content

treatment and handling

Produces upgraded oil with similar

properties and distillates yields than

light crude oils. Example, upgrades

heavy oil from 10 to 23 ° API and

reduces total sulphur from 5.7 to 1.1%

Demonstrated at semi-industrial level:

• Tested with heavy crude oil of 10,

13 and 16° API

• The upgraded oil showed important

increases in API gravity and

reduction in impurities content

• Sediment formation was kept at low

values, ensuring the stable and

secure operation of the process

Application in a refining scheme and

its comparison with delayed coking

The HIDRO-IMP® technology:

• Increases the quality and yield of

fractions (mainly gas oil and middle

distillates)

• Higher of production of gasoline, jet

fuel, and diesel

• Lower production and better quality

coke




12 Real time hydraulic fracturing monitoring system

Uncertainty about the orientation

and geometry of hydraulic

fractures

Difficulty in assessing the

behavior of the flow of fluids from

the hydraulic fracture into the

well

Improve operations fracking

process

Real-time monitoring fracturing

process, both in field and in client

facilities

Unit for real-time monitoring of

hydraulic fracturing

Models and software for

planning, monitoring and

analysis of hydraulic fracturing

operations both in real time and

offline

Includes treatment development

and hydraulic fracture

propagation

Improve the estimation of both

geometry and orientation of

hydraulically induced fractures in

wells

Real time hydraulic fracturing monitoring

system

Real time microseismic

monitoring

Foresight and analysis of

productivity


Real-time display of hydraulic

fracturing propagation allows a

better stimulation for increased

production, reduction of

treatment costs, subsequent

remediations and environmental

risks

Services may be designed for a

specific geometry of fracture.

Operator may reduce consume

of fracturing fluid and proppant

Production and recovery are

maximized




Communication system

Real time hydraulic fracturing monitoring system

Proppant 3D analisys




13 Laboratorio Móvil de Trazadores

Detectar y cuantificar trazadores,

radioactivos y químicos, en la

localización del pozo en tiempo

real

Soporte para la información

confiable de propiedades del

yacimiento en el proceso de

inyección de fluidos con fines de

recuperación de hidrocarburos

Unidad móvil con laboratorio

integrado, enfocada al diseño de

pruebas de trazadores en

yacimientos para caracterización

dinámica y estimación de

saturación remanente de aceite

Tecnología de vanguardia para

diseñar, ejecutar e interpretar

pruebas de trazadores para

obtener información adicional

para los proyectos de

recuperación de hidrocarburos

• Apto para trazadores químicos

y radioactivos

• Detecta y cuantifica trazadores

in situ en tiempo real

• Contiene un equipo único en el

mundo, EMELITRA® con

innovación disruptiva

•Adaptación a diferentes

escenarios para la aplicación de

pruebas de trazadores

Beneficios económicos:

• Por uso de EMELITRA®

(trazadores radioactivos)

reducción de costos de

99.07% / muestra y reducción

de tiempos de 97.8% / muestra

• Por uso de cromatógrafo (

trazadores químicos)

reducción de costos 51.67% /

muestra y reducción de

tiempos de 97.8% / muestra





13 Mobil Unit Tracers

Detect and quantify radioactive

and chemical tracers, located in

the well in real time

Support for reliable information

on reservoir properties in the

fluid injection process for

hydrocarbon recovery purposes

Unit with integrated laboratory,

focused on the design of tracer

tests in reservoirs for dynamic

characterization and estimation

of remaining oil saturation

State-of-the-art technology for

designing, executing and

interpreting tracer tests to obtain

additional information for

hydrocarbon recovery projects

• Suitable for chemical and

radioactive tracers

• Detects and quantifies in situ

tracers in real time

• Contains a unique equipment

in the world, named

EMELITRA® that contains

disruptive innovation

• Application of tracer tests in

different scenarios

Economic benefits:

• EMELITRA® (radioactive

tracers) generates cost

reduction of 99.07% / sample

and time reduction of 97.8% /

sample

• Chromatograph (chemical

tracer) generates cost

reduction of 51.67% / sample

and time reduction of 97.8% /

sample





Contacts

Ernesto Ríos Patrón

Chief Executive Officer

[email protected], phone: 9175-6122

Jorge A. Mendoza Amuchástegui

Exploration and Production Services Director


Roberto Ortega Ramírez

Engineering Services Director


Rafael Ramos Palmeros

Talent Development Director


Patricia Agundis Salazar

Operation Planning Director


Gustavo Murillo Muñeton

Upstream Research Director


Florentino Murrieta Guevara

Downstream Research Director


Marco A. Osorio Bonilla

Product Technology Director


José Chávez García

Marketing Strategies Manager


mailto:[email protected]









new technologies - gob.mx · 2019-05-14 · new antiscales chemicals series imp-esim • secondary...

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