COMPONEX-21 (Reservoir properties stabilizer) NOVA Technologies LLC.

COMPONEX-21COMPONEX-21(Reservoir properties stabilizer)(Reservoir properties stabilizer)

NOVA Technologies LLCNOVA Technologies LLC

Reagent Componex-21 appearanceReagent Componex-21 appearance

Componex-21 concentration in water solution Surface tension of water solution, s, Din/cm

Reference (without Componex-21) - 0% 17.34

0.01 14.99

0.025 12.36

0.05 10.76

0.06 6.56

0.075 5.31

0.1 4.64

0.2 2.70

0.3 2.12

0.5 1.31

1.0 1.17

Water solutions should not form water barriers and should lower capillary pressures in the rock pores through lowering the interface tension on the working solution – formation fluid interface boundary. Tests showed that application of water solutions containing Componex-21 lower the surface tension on the kerosene – water solution boundary. The table below shows Componex-21 concentration effect on surface tension.

Componex-21Componex-21

Lowering interface tension in water Lowering interface tension in water solution solution

Componex-21 concentration in acid solution Surface tension of water solution, s, Din/cm

12%HCl+4%HF 13.96

12%HCl+4%HF+0.04% К-21 8.00

12%HCl+4%HF+0.1% К-21 7.08

12%HCl+4%HF+0.3% К-21 2.77


Lowering interface tension in acid Lowering interface tension in acid solutionsolution

Surface tension on the kerosene – mud acid with Componex-21 solution interface boundary

Componex-21 concentration in acid solution

Solubility (%) during the time below (minutes)

30 60 90 120

12%HCl+4%HF 2.6 7.3 13.5 23.3

12%HCl+4%HF+0.04% К-21 2.0 6.0 12.5 19.6

12%HCl+4%HF+0.02% К-21 2.5 7.2 13.0 23.2

8%HCl+2%HF 2.0 6.8 13.1 17.6

8%HCl+2%HF+0.04% К-21 1.8 5.6 12.0 15.1

8%HCl+2%HF+0.02% К-21 2.0 6.2 12.9 17.1

Oil-wetting of the carbonate surface with the acid solution containing Componex-21 (evaluated indirectly, by the rate of crushed marble dissolving in acid solution)


Surface oil-wettingSurface oil-wetting

0

0,3

0,6

0,9

0 1 2 3 4 5 6 7 8 9

Обьем CaCl2, см3

D, ед.

Глинокислота ГК+вар 1 ГК+вар 2

ГК+Copmonex-21 ГК+2%лим.китслоты+0,5%гидрофоб.

Measured by optical density of 10 cm3 mud acid with adding 100 g/l calcium chloride solution(Componex-21 concentration is 5.0 g/dm3)


Inhibition of salt sedimentationInhibition of salt sedimentation

Sedimentation of insoluble salts in:12% HCl + 4% HF + 0.5 % Componex-21 (left-hand)12% HCl + 4% HF + 2% CH 3 COOH + 2% SinolKam (right-hand)

Vial 1 – an acid composition without iron, 30 minutes on a water bath at the static bottomhole temperature 46 0С.

Vial 2 – an acid composition, 2000 ррm iron solution, at the room temperature.

Vial 3 - an acid composition, 2000 ррm iron solution, 30 minutes on a water bath at the static bottomhole temperature 46 0С.

No turbidity or sediment observed after stable heating for 30 minutes. The color of the solutions in the presence of 2000ppm Fe3+ remained practically the same.

Laboratory studies on Componex-21Laboratory studies on Componex-21Test on forming a gel in the presence of Test on forming a gel in the presence of

iron ionsiron ions

Parameter name No. No.

Reagent name Measuring unit

Result

Kinematical viscosity (VPZh-2 at 20 0С)

1 12% HCI without additives mm2/sec

1.1561

2 12% HCI+ Componex-21

1.1561

3 12% HCI+ 2000 ppm Fe3+

1.2402

4 12% HCI+ 2000 ppm Fe3+ + Componex-21

1.2087

Total iron content (KFK-3)

1 12% HCI without additivesppm

1.9

2 12% HCI+ Componex-21 The instrumentation sensitivity was insufficient to measure total iron content

As seen from the above data, the kinematical viscosity and total iron content lowered. The lowered viscosity means that Componex-21 prevented forming a gel.


Inhibition of salt sedimentation (forming Inhibition of salt sedimentation (forming no gel)no gel)

Optical density of the acid solutions as a function of their depletion (exhaustion) in the presence of iron ions.


Inhibition of salt sedimentationInhibition of salt sedimentation

Plates weight, g

Loss, g Specimen surface, cm2 Result, g/cm2

before after

42.3425 42.1380 0.2045 34.25 0.0059708

Test on corrosion propagation rate


Inhibition of corrosionInhibition of corrosion

Vial No. Acid / oil НСI, 12% Test time, minutes Emulsion separation %

Filtration through

sieve

4 25/75 active 30 100 No sediment

or emulsion

5 50/50 active 30 100

6 75/25 active 30 100

LaboratoryLaboratory studies on studies on Componex-21 Componex-21Test on forming an emulsionTest on forming an emulsion

Result of filtration through 100 mc sieve. No sediment observed after filtration through the sieve. Water hardly passes through the sieve. The last case required about 500 ml water.

LaboratoryLaboratory studies on studies on Componex-21 Componex-21Test on forming an emulsionTest on forming an emulsion

Componex-21 based technologies Componex-21 based technologies applied on oilfieldsapplied on oilfields

Production or injection well treatment includes injection of a water solution containing Componex-21 into the bottomhole formation zone and reaction.

Bottomhole zone treatment with acid compositions by NOVA technologies (water solutions based on HCl or mud acid with hydrocarbon solvents and Componex-21).

Well killing technology Well killing technology using multifunctional killing using multifunctional killing

compositionscompositions

Purpose:The technology is designed to kill producing wells in oil reservoirs A, B, Yu in West Siberia fields.

Features:The technology is intended to prevent decrease of the natural productivity of formations and to prevent decrease of well production rate.Advantages:

inhibition of clay swellinglow interfacial tension of the composition on the oil boundaryprevention of salt deposition in formation pores and on subsurface oilfield

equipmentcapability to kill wells with solutions having density from 1.0 g/cm3 to 1.32

g/cm3. Opportunities: Adaptation of the technology and compositions proposed to field conditions

of particular fields at any point in the world.

Well killing technology using multifunctional killing Well killing technology using multifunctional killing compositionscompositions

Well killing technology using multifunctional Well killing technology using multifunctional killing compositionskilling compositions

Welldevelopment

Pumping of killingliquid

Technologicalcuring

kil

lin

g li

qu

id

kil

lin

g li

qu

id

oil c

apsu

le

Concentration of chemical

agent, %

Water mineralization,

g/l

Testing temperature, 0C

20 40 70 90

before after before

after before

after before

after

0.0115 TS* TS TS TS TS TS TS TS

250 TS TS TS TS TS TS TS TS

0.1



250 ( CaCl2 ) TS TS TS TS TS TS TS TS

0.5




1




2




Compatibility of Componex-20 multifunctional composition with a salty medium typical for beds A, B, Yu:

TS – transparent solution

0 10 20 30 40 50 60 70 80 90

100

120 140 160 180 200 220 240 260 Time, minutes

Swelling ability, %

Sub-commodity water

Sub-commodity water with С-20 reactant

Effect of Componex-20 multifunctional composition on bentonite swelling ability (typical for formations Yu and B16-18) in killing with solutions based on service water

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1.0

0 5 10 15 20 25 30 35 40 45 50 55 60 65

Pumped volume, Vpor

Rel

ati

ve

per

mea

bilit

y, u

nit

sh

are

s

Oil m

odel

filtr

atio

n

Sal

t w

ater

solu

tion f

iltr

atio

n

Oil m

odel

filtr

atio

n

Sal

t w

ater

solu

tion f

iltr

atio

n

Oil m

odel

filtr

atio

n

Solution ofNaCl

"C-20"

"KCL"

Sal

t w

ater

solu

tion f

iltr

atio

n

Oil m

odel

filtr

atio

n

Relative oil permeability behavior after multiple filtration of killing solutions based on different compositions through a core specimen from formation Yu

(the specimen is provided by TNK-BP, Los-Eganskoye field)

Performance characteristics of wells in different Performance characteristics of wells in different oilfieldsoilfields

Well killing technology using multifunctional killing Well killing technology using multifunctional killing compositionscompositions

Field Number of wells

Oil flow rate t/day Water cut, %

before killing

after killing

before killing after killing

RosNeft OJSC 18 1.63 2.24 84.4 76.7

Sutorminskoye field GAZPROMNEFT OJSC 108 5,66 6.18 73.6 72

Western Surgut filedSurgutNefteGas OJSC 165 17.6 22.8 56.1 55.8

Mamontovskoye field YuganskNefteGas OJSC

ROSNEFT87 22.2 25.3 52.1 50.6

378

Purpose – The technology is invented to enhance production well flow rate through improvement of the filtration properties of the bottomhole formation zone.

Features – The technology is aimed at liquidation of capillary bound water zones and involving low-permeability intervals into production through modifying the pore space wetting type, cleaning of the bottomhole formation zone from various salt and organic sediments with a partial dissolution of carbonates and bound water removal.

Advantages – a dry water-soluble reagent forming no lumps when frozen. Water solutions containing at least 6% (volume) of Componex-21 have the following characteristics: a low interface tension, prevented forming capillary bound water zones, involving low-permeability intervals, highly oil-wettable surfaces, low corrosive activity.

Technology for production well treatment with a Technology for production well treatment with a waterwater solution solution based on Componex-21based on Componex-21

Description of formations where bottomhole zones were treated with Componex-21Formation D2stIV

Lithologically, formation D2stIV is formed by sandstone and siltstone sandwiching with thin (0.1-0.5 m) argillite interlayers. The sandstones are small- to medium-grained, dense, often fractured. In addition to massive varieties, there are also big- and small-plate ones observed. A discontinuous slanted wavy and lens-like layering caused by small clay films can be noticed.The siltstones are dense, containing vegetative detritus and a bituminous substance.The argillites are tabular, with slikensides and coalificated inclusions of vegetative detritus.The clay cement is of a chlorite, chamosite type. The carbonate cement is of calcite and fine-crystalline siderite. The cement percentage is 3-10 % to 30-40 %.Quartz forms 75-98% of the rock. Its grains are packed rather tightly. The quartz has a straight and wavy fading, often fractured. The predominant sandstone fraction size is 0.1-0.25 mm. The reservoir caly content is 2.1-14.1%, averaging 6.3%. the carbonate content is minor, 0.5-3.8%.From core analysis, the open porosity of the reservoirs varies from 6 % to 19.4 %, mostly porosity is 14-16%, averaging 13.9%. The gas permeability of the reservoirs varies from 1.0 to 1350.3*10-3 mcm2 , with its geometric average value equal to 199.5*10-3 mcm2. Most core samples analyzed have permeability higher than 100.0*10-3 mcm2 .

Formation D2еf (member III)Lithologically, formation D2еf (member III) is close to formation D2stIV. The clay fraction content varies from 9.1 to 36.0 % of the rock, averaging 23.1%. The carbonate content ranges fromт 0.4 to 6.5% (with its average value 2.5 %). The open porosity averages 10.6 %. The gas permeability of the reservoirs varies in the range of 10 - 15*10-3 mcm2.

Results of testing Componex-21 in Komi Republic, well Results of testing Componex-21 in Komi Republic, well 603 on Zapadno-Synatyskoe field603 on Zapadno-Synatyskoe field

Well 603 production rate behavior after treatment of bottomhole formation zone with 6% Componex-21 water solution

Technology for bottomhole zone treatment with Componex-21 acid Technology for bottomhole zone treatment with Componex-21 acid solutions in low-permeability reservoirs solutions in low-permeability reservoirs

Purpose - The technology is invented to enhance flow rates of injection and production well through improvement of the filtration properties of the bottomhole formation zone. The technology is used for HCl and mud acid formation treatments.

Features: The technology features an integral effect on the bottomhole zone due to an enhanced permeability through: dissolving the carbonate and silicate components of the rockdisplacement of the bound-water phaseprevention of salt sedimentationwashing out salt and organic sedimentscleaning the bottomhole zone.

Advantages: a low interface tension (0.01-0.1 mN/m)a 1.5-2 times higher permeabilityinvolving low-permeability intervalsincreasing the treatment radiuslowering the corrosive activity.

Analysis of results of bottomhole zone treatment with Analysis of results of bottomhole zone treatment with Componex-21Componex-21

Oil production rate before and after bottomhole zone treatment

0

2

4

6

8

10

12

1 9 17 25 33 41 49 57 65 73 81 89 97 105 113 121 129 137 145 153

ПСКО 2010 г.

ПСКО 2012 г.

0

10

20

30

40

50

60

70

80

90

100

1 9 17 25 33 41 49 57 65 73 81 89 97 105 113 121 129 137 145 153

ПСКО 2010 г.

ПСКО 2012 г.

Water content before and after bottomhole zone treatment

0

200

400

600

800

1000

1200

1 9 17 25 33 41 49 57 65 73 81 89 97 105 113 121 129 137 145 153

ПСКО 2010 г.

ПСКО 2012 г.

Dynamic level before and after bottomhole zone treatment

Oil production rate after the interval HCl treatment in 2012 was twice higher that the basic one, lasted for 20 days.Oil production rate after the interval HCl treatment in 2010 was one and a half times higher that the basic one, lasted for five days.Water content after the interval HCl treatment in 2012 was twice lower that the basic one, lasted for 20 days.Water content after the interval HCl treatment in 2010 was not lower that the basic one.Dynamic level after the interval HCl treatment in 2012 was 200 m higher that the basic one in 20 days.Dynamic level after the interval HCl treatment in 2010 was equal to the basic one in two days.


Oil production rate before and after bottomhole zone treatment Water content before and after bottomhole zone treatment

0

1

2

3

4

5

6

7

1 9 17 25 33 41 49 57 65 73 81 89 97 105 113 121 129 137 145 153

ПСКО 2010 г.

ПСКО 2011 г.

50

55

60

65

70

75

80

85

90

95

100

1 10 19 28 37 46 55 64 73 82 91 100 109 118 127 136 145 154

ПСКО 2010 г.

ПСКО 2011 г.

Before the interval HCl treatment in 2011 (11 months after the interval HCl treatment in 2010) the well was in a periodical operation due to its high watering.After the interval HCl treatment in 2011 the well was put into operation with oil production rate of 4 ton/day.After replacing the downhole oil pump in April 2012 the well worked with production rate of 4 ton/day.


Oil production rate before and after bottomhole zone treatment Water content before and after bottomhole zone treatment

0

2

4

6

8

10

12

14

16

18

1 24 47 70 93 116 139 162 185 208 231 254 277 300 323 346 369 392 415 438 461 484

Ряд2

0

10

20

30

40

50

60

70

80

90

100

1 25 49 73 97 121 145 169 193 217 241 265 289 313 337 361 385 409 433 457 481

Ряд2

0

20

40

60

80

100

120

140

1 24 47 70 93 116 139 162 185 208 231 254 277 300 323 346 369 392 415 438 461 484

Ряд2

0

200

400

600

800

1000

1200

1 22 43 64 85 106 127 148 169 190 211 232 253 274 295 316 337 358 379 400 421 442 463 484

Ряд2

Liquid production rate before and after bottomhole zone treatment Dynamic level before and after bottomhole zone treatment

From the results of bottomhole zone treatment, the well was put out from periodical operation with a lower water content and a dynamic level 300 m higher than the basic one

Периодическая эксплуатация


Oil production rate before and after bottomhole zone treatmentWater content before and after bottomhole zone treatment

Liquid production rate before and after bottomhole zone treatment Dynamic level before and after bottomhole zone treatmentЗ

Before bottomhole zone treatment the well was in a long idling because of its high watering.After bottomhole zone treatment the watering lowered by 18%, oil production rate became 20 times higher.

0

2

4

6

8

10

12

14

16

18

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

0

10

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50

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1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

0

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1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

0

100

200

300

400

500

600

700

800

900

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

Data from monthly operation reports for the last 10 months. Before entering the well in database.






Conclusions from results of bottomhole zone treatmentConclusions from results of bottomhole zone treatment

Using 0.6% Componex-21 for bottomhole zone treatment in carbonate reservoirs gives the following results relative to ordinary HCl treatment:- lower or same watering- long-time production increase- faster well introduction in operation.

The effect can be explained by the following:- better contact between the acid solution and oil-bearing intervals- deeper solution penetration- lower water-oil emulsion volume and stability- restored original oil-wetting of the carbonate rock surface leading to lower water phase permeability and higher oil one

Componex-21 composition completely meets the above characteristics

THANK YOU FOR YOUR ATTENTIONTHANK YOU FOR YOUR ATTENTION

COMPONEX-21 (Reservoir properties stabilizer) NOVA Technologies LLC.

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Transcript of COMPONEX-21 (Reservoir properties stabilizer) NOVA Technologies LLC.