The HTBC Technology Operating Principle
Intensification of oil and gas production
The active stage of the bottomhole zone treatment starts when the two chemical COM reagents mix together at the wellbore, which causes various consequent (one initiating the other) evaporation reactions, as a result.
The released gas generates a pressure impulse that spreads in all directions. The gas flow is based on pressure and temperature changes; temperature gradient is obvious in this case – gas temperature during the in situ reaction comprises 280 ⁰C on average. Hot gas is always attracted to cold areas (in this case – to the formation), where it accumulates and gets chemically connected with the formation. During the process, gas molecules contract discretely and impulsively, which causes new fractures appearing in the rock and expanding of the existing ones. According to Griffith`s linear elastic fracture mechanics law, microfractures function as the rock stress concentrators. The fractures start expanding even if the impulses (pressure, temperature) are low enough.
In comparison to the technology of hydraulic fracturing (HF), when the fractures are provided by the physical pressure impact, the HTBC technology is based on the physicochemical in situ impact. The HTBC impact is mostly chemical, actually, because it includes such processes as nitric and hydrochloric acid vapor derivation, which provide fracturing and grain elimination, simultaneously keeping the rock structure away from destruction.
The formation water is an oxidizer and a catalyst of the reaction.
The whole formation gets covered with microfractures that remain opened without assistance.
In situ cracking (hydroconversion) reaction derives a special chemical element, called atomic hydrogen.
H1 penetrates even the most solid and dense formation and is able to create microfracture systems up to 80 and more meters in distance
The whole formation gets covered with microfractures that remain opened without assistance.
In situ cracking (hydroconversion) reaction derives a special chemical element, called atomic hydrogen.
H1 penetrates even the most solid and dense formation and is able to create microfracture systems up to 80 and more meters in distance
*Microfracture system formation
The main feature of the HTBC technology consists of unoxidized gaseous product extraction from the current borehole and their consequent in situ oxidation in the formation, which launches the thermodynamic potential of the system to its realization. It appears to be possible to provide gas generation explicitly in the formation. This process is based on the optimization law of bi-gas system convection. If a light gas (hydrogen) enters the system first and then a heavy one (carbon, nitrogen and ammonium oxides) follows it, then the convection speed and flow of the first gas augments as many times, as the heavy gas exceeds the weight of the light one. As a result, the gas flow and its filtration speed increase 7 times if hydrogen participates in the reaction.
*In situ process of cracking-pyrolysis reaction in the hydrogen environment
The HTBC technology hydroreactive compositions (HRC) are absolutely unique compounds, that allocate from 3,81 up to 5,64 cbm of hot active hydrogen (including the atomic one) from 1cbm of water. Atomic hydrogen formation and the chain of consequent reactions is an innovation of our developers. Atomic hydrogen derivation has been proved by the method of resonant-fluorescent spectroscopy. It has been also discovered that 1cm3 of gas contains 10 15 -13 hydrogen atoms (according to the GM counter).
The in situ formation temperature rises due to the process of oxidation of gaseous forms of HRC, hydrogen atom recombination and in situ combustion of the liberated oxygen.
After penetrating into the molecule through the closed pores, atoms of hydrogen recombine and allocate a quantum of energy, which causes the destruction of the closed pore and the fluid flow out.
The main advantage of the technology, that differentiates the HTBC from the others, is the fullness of extraction of hydrocarbons non-separable from the rock, which may be implemented to both oil and gas wells. The reason, why hydrocarbons are connected with the rock, is the clathrate compounds, relative to the interstitial type of compounds. Some scientists consider these compounds as complex ones, where the pre-valence layer electrons of the rock take part in the chemical connections. These compounds form a secondary structure of the substance, likewise as the hydrate compounds.
At least 40-50 percent of such hydrocarbons remain in the formation rock and are considered as non-recoverable. The HTBC technology disrupts the connections of clathrate and hydrate compounds, suppresses the hydrocarbons and fills in the empty space, derived in the formation, with its reaction products. The evidence of the technical efficiency is shown not only in experimental tests (even oil or gas scent is not detectable in the wellbores after the technology implementation) but in practice, too. For example, a Ukrainian coal basin Makeevsky had been remaining inactive for many years. In order to provide the safety of the mine, methane was extracted from the coal formation. As a result, many mine explosions were prevented this way.
The HTBC chemical systems for bottomhole zone cleansing and productivity intensification of oil and gas wells have a different composition from the traditional chemical systems used in the oil production industry, which impact is based on in situ cracking-pyrolisis of heavy hydrocarbon fractions.
The main advantage of the technology, that differentiates the HTBC from the others, is the fullness of extraction of hydrocarbons non-separable from the rock, which may be implemented to both oil and gas wells. The reason, why hydrocarbons are connected with the rock, is the clathrate compounds, relative to the interstitial type of compounds. Some scientists consider these compounds as complex ones, where the pre-valence layer electrons of the rock take part in the chemical connections. These compounds form a secondary structure of the substance, likewise as the hydrate compounds.
At least 40-50 percent of such hydrocarbons remain in the formation rock and are considered as non-recoverable. The HTBC technology disrupts the connections of clathrate and hydrate compounds, suppresses the hydrocarbons and fills in the empty space, derived in the formation, with its reaction products. The evidence of the technical efficiency is shown not only in experimental tests (even oil or gas scent is not detectable in the wellbores after the technology implementation) but in practice, too. For example, a Ukrainian coal basin Makeevsky had been remaining inactive for many years. In order to provide the safety of the mine, methane was extracted from the coal formation. As a result, many mine explosions were prevented this way.
The HTBC chemical systems for bottomhole zone cleansing and productivity intensification of oil and gas wells have a different composition from the traditional chemical systems used in the oil production industry, which impact is based on in situ cracking-pyrolisis of heavy hydrocarbon fractions.
Atoms of hydrogen recombine into a molecule, a quantum of energy is allocated. The pore gets disrupted and liberates the fluid out.
Unoxidized gaseous product extraction from the current borehole and their consequent in situ oxidation in the formation launches the thermodynamic potential of the system to its realization.
Gas flow and its filtration speed increase 7 times if hydrogen participates in the reaction.
В 1 cm3 of gas contains
10 15 -13 hydrogen atoms (according to the GM counter).
Unoxidized gaseous product extraction from the current borehole and their consequent in situ oxidation in the formation launches the thermodynamic potential of the system to its realization.
Gas flow and its filtration speed increase 7 times if hydrogen participates in the reaction.
В 1 cm3 of gas contains
10 15 -13 hydrogen atoms (according to the GM counter).
According to info on the efficiency of the technology, nearly all the wellbores exposed to treatment save the effect of the HTBC implementation from 3 up to 7 years after the procedure. For example, oil and gas wellbores, experimentally treated with the HTBC in Turkmenistan in 2010, are still working with no output decrease.
As the result of successful experimental testing, public contracts with "Turkmenneft" («Туркменнефть») and "Turkmengas" ("Турменгаз") SOEs were signed. Besides, the wellbores of the Romashkinskoye field of the Oil and Gas Production Board "Yelkhovneft" (Oil Company "Tatneft") ("Елховнефть" (ПАО «Татнефть»)) treated with the HTBC in 2013, had been working steadily for three years in a row. The research stages (explicitly after the technology implementation, in a 3-months period, in a 6-months period) show the improvement of oil composition (viscosity decrease, mechanical impurities content decrease), skin-factor decrease (from +6 to -3), structural transformation of the formation and the pressure sink generation within a radius of 80 meters from the bottomhole zone of the treated wellbore.
As the result of successful experimental testing, public contracts with "Turkmenneft" («Туркменнефть») and "Turkmengas" ("Турменгаз") SOEs were signed. Besides, the wellbores of the Romashkinskoye field of the Oil and Gas Production Board "Yelkhovneft" (Oil Company "Tatneft") ("Елховнефть" (ПАО «Татнефть»)) treated with the HTBC in 2013, had been working steadily for three years in a row. The research stages (explicitly after the technology implementation, in a 3-months period, in a 6-months period) show the improvement of oil composition (viscosity decrease, mechanical impurities content decrease), skin-factor decrease (from +6 to -3), structural transformation of the formation and the pressure sink generation within a radius of 80 meters from the bottomhole zone of the treated wellbore.
The released gas generates a pressure impulse that spreads in all directions. Hot gas "heads towards" the formation, where it accumulates and gets chemically connected with the formation.
During the process, gas molecules contract discretely and impulsively, which causes new fractures appearing in the rock and expanding of the existing ones.
The fractures start expanding even if the impulses (pressure, temperature) are low enough.
The fractures start expanding even if the impulses (pressure, temperature) are low enough.
Nearly all the wellbores, exposed to treatment, save the effect of the HTBC implementation from 3 up to 7 years after the procedure. Some wellbores save the effect for 7+ years.
The quantity of chemical agents used within the HTBC implementation is ≈1 м3 of redox mixtures. The treatment is performed by a standard workover crew. If a wellbore is able to support free circulation no additional equipment is needed. The HTBC technology solutions are lowered into the bottomhole through the tubing system.
The wellbores, equipped with a packer, may get the solutions or other chemical agents delivered to their bottomhole with the help of coiled tubing or a pump unit.
The wellbores, equipped with a packer, may get the solutions or other chemical agents delivered to their bottomhole with the help of coiled tubing or a pump unit.
*Comparison of the HTBC chemical reagents volume(1 cbm) to the technology of hydraulic fracturing reagents volume (50 tons)
From 3,81 up to 5,64 cbm
Before
Formation temperature – 500C
Wellbore temperature – 250C
from 1cbm of the liquid
After
Tpd
Tpd
*The example of 42 various oil wellbores.
The HTBC launches a chain of in situ reactions, generating a significant quantity of high-temperature chemically active gases, which cause oil fluidity and permeability increase.
In the process of oil well completion after the HTBC implementation, it is very important to select an optimal working mode of the pump unit and to provide a smooth bulking of the selected fluid because a sharp formation depression occurrence may lead to a considerable inflow, which would cause a slower oil output process.
In the process of oil well completion after the HTBC implementation, it is very important to select an optimal working mode of the pump unit and to provide a smooth bulking of the selected fluid because a sharp formation depression occurrence may lead to a considerable inflow, which would cause a slower oil output process.
The wellbore must be provided with:
• hermetical lock valves of upstream and downstream lines;
• wellbore overhaul aids station to handle the tubing;
• high-pressure pump unit;
• process water (density is 1-1,3 g/cm3) tanks for wellbore cleanout and solution depression;
• 220W electrical power unit.
• hermetical lock valves of upstream and downstream lines;
• wellbore overhaul aids station to handle the tubing;
• high-pressure pump unit;
• process water (density is 1-1,3 g/cm3) tanks for wellbore cleanout and solution depression;
• 220W electrical power unit.
*The wellbore must be killed for the period of the procedure
2. Lower the tubing to the bottomhole.
3. Pump in solution #1 (the solution density is 1.3 to 1.4 g/cm3) into the bottomhole.
4. Lift the tubing to 20 m above the uppermost perforation zone.
5. Pump in solution #2 together with the flushing fluid until the outpour.
3. Pump in solution #1 (the solution density is 1.3 to 1.4 g/cm3) into the bottomhole.
4. Lift the tubing to 20 m above the uppermost perforation zone.
5. Pump in solution #2 together with the flushing fluid until the outpour.
Pumping the solution #1(density is 1,3 - 1,4 g/сm3) into the bottomhole zone
Pumping the solution #2 into the bottomhole zone through the flush fluid (density is 1,6 g/cm3)
Mixing the solutions in the bottomhole of the wellbore. The reaction starts, producing various gases (H, H2, CO, NH3, NO, N2, O2, CO2, N2O3, N2O5, NO2, BO, HCL, HNO3).
*Pumping the neutralizing tank presented as 6% HCL
* Activating the next step of the reaction. The process of neutralization
*Hot acid vapors (HCL, HNO2, HNO3) liberation. Temperature rise
1. Before the COM application, fill the wellbore with a kill fluid of ≤1,3g/сm3 density. Check the bedrock intake.
6. Leave the well for 12 hours for the reaction process.
7. Close the annular space and inject the reaction products into the formation.
7. Close the annular space and inject the reaction products into the formation.
8. Опустить НКТ до верхних отверстий перфорации.
9. Закрыть затрубное пространство и закачать в пласт раствор №3 для нейтрализации и удаления образовавшихся коллоидных систем.
10. Освоить скважину.
9. Закрыть затрубное пространство и закачать в пласт раствор №3 для нейтрализации и удаления образовавшихся коллоидных систем.
10. Освоить скважину.
8. Lower the tubing back to the uppermost perforation holes.
9. Close the annular space and pump in solution #3 into the formation to neutralize and remove the formed colloid systems.
10. Complete the well.
9. Close the annular space and pump in solution #3 into the formation to neutralize and remove the formed colloid systems.
10. Complete the well.
The Industrial Process Of the HTBC Treatment
The HTBC Microfracture formation
Typical oil-saturated formation:
• Oil covers the inside walls of the pore.
• Water.
Divergent rock pores may contain oil, water and water-oil emulsion as well.
• Oil covers the inside walls of the pore.
• Water.
Divergent rock pores may contain oil, water and water-oil emulsion as well.
• In the course of hydro-cracking reaction the atomic hydrogen(H1) liberation occurs.H1 penetrates the rock easily as it is the smallest atom of the periodic table. Atomic hydrogen (H1) may penetrate any solid material and recombine into the H2 molecule, which fills in all the open space of the rock.
After H1recombination, a quantum of energy is allocated into the molecule, which causes the destruction of the closed pore. Following the atomic hydrogen, a complex of chemically active heavy gases enters the formation, bubbles of which create a whole fluid-trap system. The reactions proceed impulsively. The liberated gas impulse provides a pressure change impulse.As a result of the reaction, a system of microfractures is formed.
The microfracture system is ready. When multiple systems join together, the new permeability channels appear in the formation.
The Process Stages and the Result
Process stage
The well is killed. The tubing is lowered to the current bottomhole.
Solution #1(density is 1.3 kg/dm3) is pumped into the bottomhole
Solution #1(density is 1.3 kg/dm3) is pumped into the bottomhole
Outcome
The solution is in the bottomhole and does not react.
Process stage
Lifting the tubing by 25 to 30 meters above the uppermost perforation zone.
Pumping solution #2 with a density of 1.6 kg/dm3 together with the flushing fluid. The annular space is closed.
Acid vapor formation (also during the reaction with the killing fluid) and accumulation (explicitly in the bedrock pores).
Pumping solution #2 with a density of 1.6 kg/dm3 together with the flushing fluid. The annular space is closed.
Acid vapor formation (also during the reaction with the killing fluid) and accumulation (explicitly in the bedrock pores).
Outcome
The second solution is mixed with the first one. For some chemical reactions of the stage, the intermediate components and the basic final products are shown . An exothermal reaction with a temperature increase by 80 to 100 ºC.
NaNO2 + NH4Cl = NaCl + N2 + 2 H2O
NaNO2 + NH4NO3 = NaNO3 + N2 + 2H2O
2NaNO3 = Na2O + N2O5
Na2O + H2O = 2NaOH
Decomposition of carbamide nitrate during the reaction with water.
CO(NH2)2 ·HNO3 = 2NH3 + CO2 + HNO3(gas)
NH4Cl = NH3 + HCl
Further decomposition of carbamide (urea)
3CO(NH2)2 = 3CO + 4 NH3 + N2
CO(NH2)2 + H2O = 2NH3 + CO2
Heating of the formation bottomhole zone for 30 to 40 minutes (time-controlled process).
NaNO2 + NH4Cl = NaCl + N2 + 2 H2O
NaNO2 + NH4NO3 = NaNO3 + N2 + 2H2O
2NaNO3 = Na2O + N2O5
Na2O + H2O = 2NaOH
Decomposition of carbamide nitrate during the reaction with water.
CO(NH2)2 ·HNO3 = 2NH3 + CO2 + HNO3(gas)
NH4Cl = NH3 + HCl
Further decomposition of carbamide (urea)
3CO(NH2)2 = 3CO + 4 NH3 + N2
CO(NH2)2 + H2O = 2NH3 + CO2
Heating of the formation bottomhole zone for 30 to 40 minutes (time-controlled process).
Process stage
150 ºС is the temperature when hydroreactive compositions (HRC) start proceeding.
Further temperature rise to 250 ºС.
Further temperature rise to 250 ºС.
Outcome
Liberation of atomic hydrogen from water.
C3B10H18 + 21 H2O = 3 CO2 + 5 B2O3 + 30 H2
B6O + 8H2O = 3B2O3 + 8 H2 :
a) B6O + 5H2O = 6BO + 10H
b) 2BO + H2O = B2O3 + 2H
c) H + H = H2
Pressure increase. Hydrogen diffuses into the productive layer and improves its diffusion properties. This hydrogen property is anomalous as many other ones are (see the commentary).
C3B10H18 + 21 H2O = 3 CO2 + 5 B2O3 + 30 H2
B6O + 8H2O = 3B2O3 + 8 H2 :
a) B6O + 5H2O = 6BO + 10H
b) 2BO + H2O = B2O3 + 2H
c) H + H = H2
Pressure increase. Hydrogen diffuses into the productive layer and improves its diffusion properties. This hydrogen property is anomalous as many other ones are (see the commentary).
Process stage
Dehydration and decomposition of complex compounds.
Outcome
Temperature rise up to 300 - 350 ºС.
Process stage
Liberation of the following gases: СО, СО2, N2,NO2, N2O5 (shown in blue); heat-up and evaporation of nitric and hydrochloric acid (hydrofluoric acid can be included).
Outcome
A heterophase medium is formed: liquid –gas-vapor of active components.
The permeability of vapor is significantly higher than that of a liquid. This mixture affects the bottomhole zone of the formation.
The reactions of acids with rock and ARPD are shown below:
Na2SiO3 + 2HCl = 2NaCl + H2SiO3 Na2SiO3 +
2CH3COOH = 2CH3COONa + H2SiO3
NH3+ H2O = NH4OH
SiO2+ 2NH4OH = (NH4)2SiO3+H2O
SiO2 + 2 NaOH = Na2SiO3 + H2O
Al2O3 + 2NaOH = 2NaAlO2 +H2O
Al2O3 + 6HNO3 = 2Al(NO3)3 +3H2O
Al2O3+6HCl =2AlCl3+3H2O
MgO+N2O5 = Mg(NO3)2
CaO+N2O5 = Ca(NO3)2
(NH4)2SiO3 + 2HCl = 2NH4Cl +H2SiO3
Na2SiO3 + 2HCl = 2NaCl + H2SiO3
The chemistry of carbonates with hydrochloric acid is also well known. One should only take into account that the effectiveness of hot acid treatment is drastically higher than that at low temperatures.
Chlorides, nitrates and nitrides are soluble in water and are washed out easily.
Carbon dioxide reduces oil viscosity. The oxide is partially transformed into carbonic acid, and also participates in formation of clathrate compounds and improves the formation permeability.
The permeability of vapor is significantly higher than that of a liquid. This mixture affects the bottomhole zone of the formation.
The reactions of acids with rock and ARPD are shown below:
Na2SiO3 + 2HCl = 2NaCl + H2SiO3 Na2SiO3 +
2CH3COOH = 2CH3COONa + H2SiO3
NH3+ H2O = NH4OH
SiO2+ 2NH4OH = (NH4)2SiO3+H2O
SiO2 + 2 NaOH = Na2SiO3 + H2O
Al2O3 + 2NaOH = 2NaAlO2 +H2O
Al2O3 + 6HNO3 = 2Al(NO3)3 +3H2O
Al2O3+6HCl =2AlCl3+3H2O
MgO+N2O5 = Mg(NO3)2
CaO+N2O5 = Ca(NO3)2
(NH4)2SiO3 + 2HCl = 2NH4Cl +H2SiO3
Na2SiO3 + 2HCl = 2NaCl + H2SiO3
The chemistry of carbonates with hydrochloric acid is also well known. One should only take into account that the effectiveness of hot acid treatment is drastically higher than that at low temperatures.
Chlorides, nitrates and nitrides are soluble in water and are washed out easily.
Carbon dioxide reduces oil viscosity. The oxide is partially transformed into carbonic acid, and also participates in formation of clathrate compounds and improves the formation permeability.
Process stage
Temperature, pressure, atomic hydrogen, the injected catalysts and rock take part in the cracking process and pyrolysis of heavy hydrocarbons.
Outcome
ARPD hydroconversion, and transformation into volatile and gasoil fractions. The carbon also participates in the reaction of conversion, especially if the formation water is in the bedrock.
Process stage
In situ combustion ensures the unique component, a polymer nitrile paracyanogen (C2N2)n, presence in the compound. Its minimal amount (0.01 %) ensures chain oxidation.
Outcome
The in situ combustion with nitriles ensures the further improvement of the formation properties, also due to volume increase of newly-formed combustive compositions. The remains of inactivated hydrogen are additionally oxidized in the following reaction:
(C2N2)n = nC2N2
C2N2 + O2 = 2CO + N2
(C2N2)n = nC2N2
C2N2 + O2 = 2CO + N2
- C2N2 + 2 O2 = 2CO + 2O+ N2
- C + O= CO
- C + 2O= CO2
Process stage
In 12 and more hours, the tubing is lowered to the level of the uppermost perforation zone. An alkali medium (NaOH) remains in the bottomhole, which is neutralised by a weak acid solution.
Outcome
The system is neutralized. The well is ready for production.
Process stage
Outcome
The well is killed. The tubing is lowered to the current bottomhole.
Solution #1(density is 1.3 kg/dm3) is pumped into the bottomhole
Solution #1(density is 1.3 kg/dm3) is pumped into the bottomhole
The solution is in the bottomhole and does not react.
Lifting the tubing by 25 to 30 meters above the uppermost perforation zone.
Pumping solution #2 with a density of 1.6 kg/dm3 together with the flushing fluid. The annular space is closed.
Acid vapor formation (also during the reaction with the killing fluid) and accumulation (explicitly in the bedrock pores).
Pumping solution #2 with a density of 1.6 kg/dm3 together with the flushing fluid. The annular space is closed.
Acid vapor formation (also during the reaction with the killing fluid) and accumulation (explicitly in the bedrock pores).
The second solution is mixed with the first one. For some chemical reactions of the stage, the intermediate components and the basic final products are shown . An exothermal reaction with a temperature increase by 80 to 100 ºC.
NaNO2 + NH4Cl = NaCl + N2 + 2 H2O
NaNO2 + NH4NO3 = NaNO3 + N2 + 2H2O
2NaNO3 = Na2O + N2O5
Na2O + H2O = 2NaOH
Decomposition of carbamide nitrate during the reaction with water
CO(NH2)2 ·HNO3 = 2NH3 + CO2 + HNO3(gas)
NH4Cl = NH3 + HCl
Further decomposition of carbamide (urea)
3CO(NH2)2 = 3CO + 4 NH3 + N2
CO(NH2)2 + H2O = 2NH3 + CO2
Heating of the formation bottomhole zone for 30 to 40 minutes (time-controlled process).
NaNO2 + NH4Cl = NaCl + N2 + 2 H2O
NaNO2 + NH4NO3 = NaNO3 + N2 + 2H2O
2NaNO3 = Na2O + N2O5
Na2O + H2O = 2NaOH
Decomposition of carbamide nitrate during the reaction with water
CO(NH2)2 ·HNO3 = 2NH3 + CO2 + HNO3(gas)
NH4Cl = NH3 + HCl
Further decomposition of carbamide (urea)
3CO(NH2)2 = 3CO + 4 NH3 + N2
CO(NH2)2 + H2O = 2NH3 + CO2
Heating of the formation bottomhole zone for 30 to 40 minutes (time-controlled process).
Liberation of atomic hydrogen from water.
C3B10H18 + 21 H2O = 3 CO2 + 5 B2O3 + 30 H2
B6O + 8H2O = 3B2O3 + 8 H2 :
C3B10H18 + 21 H2O = 3 CO2 + 5 B2O3 + 30 H2
B6O + 8H2O = 3B2O3 + 8 H2 :
- B6O + 5H2O = 6BO + 10H
- 2BO + H2O = B2O3 + 2H
- H + H = H2
150 ºС is the temperature when hydroreactive compositions (HRC) start proceeding.
Further temperature rise to250 ºС.
Further temperature rise to250 ºС.
Dehydration and decomposition of complex compounds.
Temperature rise up to 300 - 350 ºС.
A heterophase medium is formed: liquid –gas-vapor of active components.
The permeability of vapor is significantly higher than that of a liquid. This mixture affects the bottomhole zone of the formation.
The reactions of acids with rock and ARPD are shown below:
NH3 + H2O = NH4OH
SiO2 + 2NH4OH = (NH4) 2SiO3 + H2O
SiO2 + 2 NaOH = Na2SiO3 + H2O
Al2O3 + 2NaOH = 2NaAlO2 + H2O
Al2O3 + 6HNO3 = 2Al (NO3)3 + 3H2O
Al2O3 + 6HCl = 2AlCl3 + 3H2O
MgO + N2O5 = Mg (NO3)2
CaO + N2O5 = Ca (NO3)2
(NH4) 2SiO3 + 2HCl = 2NH4Cl + H2SiO3
Na2SiO3 + 2HCl = 2NaCl + H2SiO3 Na2SiO3 +
2CH3COOH = 2CH3COONa + H2SiO3
The chemistry of carbonates with hydrochloric acid is also well known. One should only take into account that the effectiveness of hot acid treatment is drastically higher than that at low temperatures.
Chlorides, nitrates and nitrides are soluble in water and are washed out easily.
Carbon dioxide reduces oil viscosity. The oxide is partially transformed into carbonic acid, and also participates in formation of clathrate compounds and improves the formation permeability.
The permeability of vapor is significantly higher than that of a liquid. This mixture affects the bottomhole zone of the formation.
The reactions of acids with rock and ARPD are shown below:
NH3 + H2O = NH4OH
SiO2 + 2NH4OH = (NH4) 2SiO3 + H2O
SiO2 + 2 NaOH = Na2SiO3 + H2O
Al2O3 + 2NaOH = 2NaAlO2 + H2O
Al2O3 + 6HNO3 = 2Al (NO3)3 + 3H2O
Al2O3 + 6HCl = 2AlCl3 + 3H2O
MgO + N2O5 = Mg (NO3)2
CaO + N2O5 = Ca (NO3)2
(NH4) 2SiO3 + 2HCl = 2NH4Cl + H2SiO3
Na2SiO3 + 2HCl = 2NaCl + H2SiO3 Na2SiO3 +
2CH3COOH = 2CH3COONa + H2SiO3
The chemistry of carbonates with hydrochloric acid is also well known. One should only take into account that the effectiveness of hot acid treatment is drastically higher than that at low temperatures.
Chlorides, nitrates and nitrides are soluble in water and are washed out easily.
Carbon dioxide reduces oil viscosity. The oxide is partially transformed into carbonic acid, and also participates in formation of clathrate compounds and improves the formation permeability.
Liberation of the following gases: СО, СО2, N2,NO2, N2O5 (shown in blue); heat-up and evaporation of nitric and hydrochloric acid (hydrofluoric acid can be included).
Temperature, pressure, atomic hydrogen, the injected catalysts and rock take part in the cracking process and pyrolysis of heavy hydrocarbons.
ARPD hydroconversion, and transformation into volatile and gasoil fractions. The carbon also participates in the reaction of conversion, especially if the formation water is in the bedrock.
According to the TatSRPIneft (ТатНИПИнефть) , not less than 80 meters at the Tournaisian sediment
Decomposition of NH4NO3 and oxygen formation process.
In situ combustion ensures the unique component, a polymer nitrile paracyanogen (C2N2)n, presence in the compound. Its minimal amount (0.01 %) ensures chain oxidation.
In situ combustion ensures the unique component, a polymer nitrile paracyanogen (C2N2)n, presence in the compound. Its minimal amount (0.01 %) ensures chain oxidation.
The in situ combustion with nitriles ensures the further improvement of the formation properties, also due to volume increase of newly-formed combustive compositions. The remains of inactivated hydrogen are additionally oxidized in the following reaction:
(C2N2) n = nC2N2
C2N2 + O2 = 2CO + N2
а) C2N2 + 2 O2 = 2CO + 2O + N2
b) C + O = CO
в) C + 2O = CO2
In situ combustion occurs.
(C2N2) n = nC2N2
C2N2 + O2 = 2CO + N2
а) C2N2 + 2 O2 = 2CO + 2O + N2
b) C + O = CO
в) C + 2O = CO2
In situ combustion occurs.
In 12 and more hours, the tubing is lowered to the level of the uppermost perforation zone. An alkali medium (NaOH) remains in the bottomhole, which is neutralised by a weak acid solution.
The system is neutralized. The well is ready for production.
The conditions necessary for fluid in situ hydrodynamics changes are formed
It is important to take the new conditions of oil optimal selection into account
* Formation of the depression zone
Redox compound components in ready-made suspension solutions belong to the class of complex salts with addition of boron hexoxide and its intermetallic compounds.
Approximate chemical (typical) composition of redox compounds, mass share of components:
Approximate chemical (typical) composition of redox compounds, mass share of components:
water H2O
salt ammonia NH4Cl
ammonium nitrate NH4NO3
carbamide CO(NH2)2
salt ammonia NH4Cl
ammonium nitrate NH4NO3
carbamide CO(NH2)2
13 %
7%
40%
17%
7%
40%
17%
boron hexoxide, carboranes, lithium and aluminum borides B6O, LiB10, AlB12
bi-sodium salt of tetraacetic acid (complexon ІІІ)
acetic acid CH3COOH
bi-sodium salt of tetraacetic acid (complexon ІІІ)
acetic acid CH3COOH
13%
6%
4%
6%
4%
The actual component composition is much more complex due to special additives for controlling the process kinetics (activators, inhibitors and anticorrosive additives).
Depending on the well condition (the presence of high-molecular paraffin in the tubes and the productive rock to be eliminated), the content of boron intermetallic compounds, its hexoxide, carboranes and complexon ІІІ in the redox compounds can vary within 0.4 % to 20%.
Depending on the well condition (the presence of high-molecular paraffin in the tubes and the productive rock to be eliminated), the content of boron intermetallic compounds, its hexoxide, carboranes and complexon ІІІ in the redox compounds can vary within 0.4 % to 20%.
Treated with atomic hydrogen
Treated with molecular hydrogen
Untreated
The HTBC effect on the timeline
Temperature of H,H2,CO,NOx,O2
20 reactions:
- existing
- modified
- new
- existing
- modified
- new
-cracking
- pyrolisis
- fracturing
Minutes
Hours
Months
Years
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© LLC "Clean Energy"
