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3 Status Quo of Methods for Evaluating Filtration Performance and Mud Cake Quality of Drilling Fluid
4 Progresses in Studying Drilling Fluid Nano Material Plugging Agents
5 Drilling Fluid Technology for “Three High” Wells in Qaidam Basin in Qinghai
6 Synthesis and Evaluation of A Primary Emulsifier for High Temperature Oil Base Drilling Fluid
7 A New Fracturing Fluid with Temperature Resistance of 230℃
8 Plugging Micro-fractures to Prevent Gas-cut in Fractured Gas Reservoir Drilling
9 Development of Extreme Pressure Anti-wear Lubricant MPA for Water Base Drilling Fluids
10 Progress in Studying Cement Sheath Failure in Perforated Wells
2 Study and Performance Evaluation of Ultra-High Temperature High Density Oil Based Drilling Fluids
3 Synthesis and Evaluation of A Primary Emulsifier for High Temperature Oil Base Drilling Fluid
4 Progresses in Studying Drilling Fluid Nano Material Plugging Agents
5 Hole Cleaning Technology for Horizontal and Deviated Drilling: Progress Made and Prospect
8 High Performance Water Base Drilling Fluid for Shale Gas Drilling
9 A New Fracturing Fluid with Temperature Resistance of 230℃
10 High Performance Water Base Drilling Fluid for Shale Gas Drilling
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2025, 42(3): 283-289.
doi: 10.12358/j.issn.1001-5620.2025.03.001
Abstract:
Studying on the hardening process of epoxy resin and the interaction between epoxy and formation minerals has important theoretical significance for their application in petroleum industry. Studies on epoxy in the past mainly focused on the properties of epoxy resin itself, with its interaction with formations being ignored. To extensively investigate the hardening process of epoxy and the interaction between epoxy and formation minerals, molecular simulation method was used to study the molecules of E51 epoxy resin and several hardening agents. The electrostatic potential and interaction energy between the molecules of epoxy and the molecules of the hardening agents, as well as the interaction energy between the products of the hardening process and the formation minerals, were calculated. It was found that the epoxy groups in the epoxy resin molecules have a significant negative potential, which is −0.060 Hartree/e, while the active hydrogen atoms in the molecules of the hardening agents have significant positive potential, ranging from 0.053 Hartree/e to 0.126 Hartree/e. Moreover, mutual attraction exists between the molecules of the epoxy resin and the molecules of the hardening agents, the energy of the attraction ranges from −0.446 kcal/mol to −29.306 kcal/mol. After crosslinking, the interaction energy between the molecules was reduced to −80.987 kcal/mol to −110.844 kcal/mol. Finally, significant mutual attraction also exists between the crosslinking product of the epoxy resin and formation minerals; the interaction energy between a single epoxy molecule and the calcite mineral in the formation ranges from −49.795 kcal/mol to −173.187 kcal/mol, while the interaction energy between a single epoxy molecule and the dolomite mineral in the formation ranges from −44.604 kcal/mol to −147.307 kcal/mol. These research achievements have provided a theoretical base for the application of epoxy resin in oil and natural gas industry, and the research method adopted can be used in optimizing the design of epoxy resin additives.
Studying on the hardening process of epoxy resin and the interaction between epoxy and formation minerals has important theoretical significance for their application in petroleum industry. Studies on epoxy in the past mainly focused on the properties of epoxy resin itself, with its interaction with formations being ignored. To extensively investigate the hardening process of epoxy and the interaction between epoxy and formation minerals, molecular simulation method was used to study the molecules of E51 epoxy resin and several hardening agents. The electrostatic potential and interaction energy between the molecules of epoxy and the molecules of the hardening agents, as well as the interaction energy between the products of the hardening process and the formation minerals, were calculated. It was found that the epoxy groups in the epoxy resin molecules have a significant negative potential, which is −0.060 Hartree/e, while the active hydrogen atoms in the molecules of the hardening agents have significant positive potential, ranging from 0.053 Hartree/e to 0.126 Hartree/e. Moreover, mutual attraction exists between the molecules of the epoxy resin and the molecules of the hardening agents, the energy of the attraction ranges from −0.446 kcal/mol to −29.306 kcal/mol. After crosslinking, the interaction energy between the molecules was reduced to −80.987 kcal/mol to −110.844 kcal/mol. Finally, significant mutual attraction also exists between the crosslinking product of the epoxy resin and formation minerals; the interaction energy between a single epoxy molecule and the calcite mineral in the formation ranges from −49.795 kcal/mol to −173.187 kcal/mol, while the interaction energy between a single epoxy molecule and the dolomite mineral in the formation ranges from −44.604 kcal/mol to −147.307 kcal/mol. These research achievements have provided a theoretical base for the application of epoxy resin in oil and natural gas industry, and the research method adopted can be used in optimizing the design of epoxy resin additives.
2025, 42(3): 290-295.
doi: 10.12358/j.issn.1001-5620.2025.03.002
Abstract:
As flexible plugging agents used in drilling fluids, gel plugging agents have great effects on the rheology of the drilling fluids, and asphalt plugging agents have fluorescent effect that interferes with mud logging data acquisition. To solve these problems, a water-based polyurethane emulsion plugging agent SMPU-1 has been prepared with the following monomers: isophorone diisocyanate (IPDI), polytetramethylene ether glycol (PO3G), 2-hydroxyethyl disulfide (HEDS) and dimethylol butyric acid (DMBA) as the chain extenders, dibutyltin dilaurate (DBTDL) as the catalyst, furfuryl alcohol (FA) as the end-capping agent, and triethylamine (TEA) as the emulsifier. Using IR spectrometer, laser particle size analyzer and scanning electron microscope, the molecular structure of SMPU-1 was characterized, and the particle size distribution and the micromorphology of SMPU-1 analyzed. It was found that under the action of high temperature, the SMPU-1 particles are still in nano-micron monodisperse state, and become soft and deformed. Under the action of pressure, the SMPU-1 particles can be squeezed into and hence densely plug the micro-fractures on the surfaces of rocks. The results of the plugging performance test show that the optimum temperature for the SMPU-1 particles to function is 140°C or lower, and the optimum treatment of SMPU-1 is 4%. SMPU-1 has little effect on the rheology of drilling fluids. At the maximum applicable work temperature and the optimum dosage, the API filter loss of a drilling fluid is 6.2 mL, and the high temperature high pressure (HTHP) filter loss is 16 mL, indicating that the drilling fluid still has good filtration and wall-building properties.
As flexible plugging agents used in drilling fluids, gel plugging agents have great effects on the rheology of the drilling fluids, and asphalt plugging agents have fluorescent effect that interferes with mud logging data acquisition. To solve these problems, a water-based polyurethane emulsion plugging agent SMPU-1 has been prepared with the following monomers: isophorone diisocyanate (IPDI), polytetramethylene ether glycol (PO3G), 2-hydroxyethyl disulfide (HEDS) and dimethylol butyric acid (DMBA) as the chain extenders, dibutyltin dilaurate (DBTDL) as the catalyst, furfuryl alcohol (FA) as the end-capping agent, and triethylamine (TEA) as the emulsifier. Using IR spectrometer, laser particle size analyzer and scanning electron microscope, the molecular structure of SMPU-1 was characterized, and the particle size distribution and the micromorphology of SMPU-1 analyzed. It was found that under the action of high temperature, the SMPU-1 particles are still in nano-micron monodisperse state, and become soft and deformed. Under the action of pressure, the SMPU-1 particles can be squeezed into and hence densely plug the micro-fractures on the surfaces of rocks. The results of the plugging performance test show that the optimum temperature for the SMPU-1 particles to function is 140°C or lower, and the optimum treatment of SMPU-1 is 4%. SMPU-1 has little effect on the rheology of drilling fluids. At the maximum applicable work temperature and the optimum dosage, the API filter loss of a drilling fluid is 6.2 mL, and the high temperature high pressure (HTHP) filter loss is 16 mL, indicating that the drilling fluid still has good filtration and wall-building properties.
2025, 42(3): 296-301.
doi: 10.12358/j.issn.1001-5620.2025.03.003
Abstract:
Difficulties such as borehole wall instability, poor hole cleaning, drag encountered frequently during tripping due to high friction and torque, and difficult reaming, have been encountered in drilling operation in the Baoyunting block and the Pinghu block in east China Sea, which seriously affect the drilling efficiency. By analyzing the characteristics of the variegated mudstone formation, a technology using sized particles to achieve strong plugging was applied and the emulsification stability of the oil-based drilling fluid was improved to solve the problem of borehole wall instability. By optimizing the 6/3 r/min reading of the drilling fluid on six-speed viscometer, efficient cuttings carrying was achieved and the problem of hole cleaning in extended-reach well drilling in the East China Sea was solved. An independently developed lubricant LUBE OB was used to reduce the friction coefficient of the drilling fluid under high loads and the wear of drill strings and casings. This oil-based drilling fluid technology was successfully applied for the first time in drilling the 8000 m ultra-deep extended-reach well KQT-N. The oil-based drilling fluid has strong plugging capacity, high cuttings carrying efficiency and high lubrication performance, the use of which has reduced the time required for reaming in extended-reach wells in the East China Sea from 16.7% to 2.0%, greatly improving the drilling efficiency and providing technical support and guarantee for the safe and efficient development of the oil and gas fields in the East China Sea.
Difficulties such as borehole wall instability, poor hole cleaning, drag encountered frequently during tripping due to high friction and torque, and difficult reaming, have been encountered in drilling operation in the Baoyunting block and the Pinghu block in east China Sea, which seriously affect the drilling efficiency. By analyzing the characteristics of the variegated mudstone formation, a technology using sized particles to achieve strong plugging was applied and the emulsification stability of the oil-based drilling fluid was improved to solve the problem of borehole wall instability. By optimizing the 6/3 r/min reading of the drilling fluid on six-speed viscometer, efficient cuttings carrying was achieved and the problem of hole cleaning in extended-reach well drilling in the East China Sea was solved. An independently developed lubricant LUBE OB was used to reduce the friction coefficient of the drilling fluid under high loads and the wear of drill strings and casings. This oil-based drilling fluid technology was successfully applied for the first time in drilling the 8000 m ultra-deep extended-reach well KQT-N. The oil-based drilling fluid has strong plugging capacity, high cuttings carrying efficiency and high lubrication performance, the use of which has reduced the time required for reaming in extended-reach wells in the East China Sea from 16.7% to 2.0%, greatly improving the drilling efficiency and providing technical support and guarantee for the safe and efficient development of the oil and gas fields in the East China Sea.
2025, 42(3): 302-307.
doi: 10.12358/j.issn.1001-5620.2025.03.004
Abstract:
In highly deviated wells, horizontal wells or large diameter wells, drilled cuttings are likely to accumulate on the lower side or at the bottom of the well due to insufficient cuttings carrying capacity of the drilling fluid. This will lead to complex downhole situations such as an increase in the friction of the drill string movement, difficulties in tripping, downhole lost circulation and even pipe sticking. Hole cleaning is therefore one of the key technologies to achieve operation safety and efficiency in highly deviated wells, horizontal wells or large diameter wells. A fiber cuttings-carrying agent that can significantly improve the cuttings carrying capacity of a drilling fluid was developed by blending and reacting an aliphatic polyester polymer with a high molecular weight copolymer. Results of performance evaluation experiments show that in the experimental slurry with 0.2% of the cuttings-carrying agent, the settling time of the cuttings increases from the original 4.12 sec to 19.85 sec. This cuttings-carrying agent has good dispersibility in both aqueous phase and oil phase. After hot rolling at 120℃ for 16 h, the degradation rates in clean water and white oil are 95.48% and 89.87% respectively, and the degradation does not affect the performance of the drilling fluid. Field tests show that this cuttings-carrying technology can significantly improve the cuttings-carrying capacity of the drilling fluid, effectively carry drilled cuttings or sloughing rock pieces out of large diameter wells or horizontal well sections, improve the wellbore cleanliness, and provide a guarantee for safe and efficient drilling.
In highly deviated wells, horizontal wells or large diameter wells, drilled cuttings are likely to accumulate on the lower side or at the bottom of the well due to insufficient cuttings carrying capacity of the drilling fluid. This will lead to complex downhole situations such as an increase in the friction of the drill string movement, difficulties in tripping, downhole lost circulation and even pipe sticking. Hole cleaning is therefore one of the key technologies to achieve operation safety and efficiency in highly deviated wells, horizontal wells or large diameter wells. A fiber cuttings-carrying agent that can significantly improve the cuttings carrying capacity of a drilling fluid was developed by blending and reacting an aliphatic polyester polymer with a high molecular weight copolymer. Results of performance evaluation experiments show that in the experimental slurry with 0.2% of the cuttings-carrying agent, the settling time of the cuttings increases from the original 4.12 sec to 19.85 sec. This cuttings-carrying agent has good dispersibility in both aqueous phase and oil phase. After hot rolling at 120℃ for 16 h, the degradation rates in clean water and white oil are 95.48% and 89.87% respectively, and the degradation does not affect the performance of the drilling fluid. Field tests show that this cuttings-carrying technology can significantly improve the cuttings-carrying capacity of the drilling fluid, effectively carry drilled cuttings or sloughing rock pieces out of large diameter wells or horizontal well sections, improve the wellbore cleanliness, and provide a guarantee for safe and efficient drilling.
2025, 42(3): 308-317.
doi: 10.12358/j.issn.1001-5620.2025.03.005
Abstract:
The flow of water based drilling fluids in slim holes fluctuate significantly and the interface resistance between the drilling fluids and the wellbore/drilling tools is high, resulting in high flow energy loss and high equivalent circulation density (ECD) which in turn cause mud losses and stuck pipe to happen. A drag reducer DRA-1 for water based drilling fluids was synthesized with nano silica as the raw material through graft-modification, and its performance was studied. In laboratory experiment, it was found that a base mud treated with 3% DRA-1 has its flow index increased by 366.7% to 0.5064, the consistency coefficient reduced by 90.6% to 0.4847 Pa·sn, and the extreme pressure coefficient of friction reduced by 81.82%. After hot rolling at 120℃ for 16 hours, the extreme pressure coefficient of friction was further reduced, indicating that DRA-1 is resistant to high temperature. When the DRA-1 treated base mud was flowing under the same conditions on a self-made steel plate and a polytetrafluoroethylene plate respectively, DRA-1 performed much better than the same type of field additives in improving the flow behavior of the mud. Operation data obtained from the well A showed that by adding 1% DRA-1 in the water based drilling fluid, the pressure loss along the circulation system was reduced by 1.937 MPa, a reduction rate of 21.61%, and lower ECD was obtained in the whole drilling operation, indicating that DRA-1 helped increase the drilling efficiency and safety, and this is very important to the increase of economic benefits and the avoidance or drilling accidents.
The flow of water based drilling fluids in slim holes fluctuate significantly and the interface resistance between the drilling fluids and the wellbore/drilling tools is high, resulting in high flow energy loss and high equivalent circulation density (ECD) which in turn cause mud losses and stuck pipe to happen. A drag reducer DRA-1 for water based drilling fluids was synthesized with nano silica as the raw material through graft-modification, and its performance was studied. In laboratory experiment, it was found that a base mud treated with 3% DRA-1 has its flow index increased by 366.7% to 0.5064, the consistency coefficient reduced by 90.6% to 0.4847 Pa·sn, and the extreme pressure coefficient of friction reduced by 81.82%. After hot rolling at 120℃ for 16 hours, the extreme pressure coefficient of friction was further reduced, indicating that DRA-1 is resistant to high temperature. When the DRA-1 treated base mud was flowing under the same conditions on a self-made steel plate and a polytetrafluoroethylene plate respectively, DRA-1 performed much better than the same type of field additives in improving the flow behavior of the mud. Operation data obtained from the well A showed that by adding 1% DRA-1 in the water based drilling fluid, the pressure loss along the circulation system was reduced by 1.937 MPa, a reduction rate of 21.61%, and lower ECD was obtained in the whole drilling operation, indicating that DRA-1 helped increase the drilling efficiency and safety, and this is very important to the increase of economic benefits and the avoidance or drilling accidents.
2025, 42(3): 318-323.
doi: 10.12358/j.issn.1001-5620.2025.03.006
Abstract:
Laboratory simulation study was conducted on the strengthening of borehole walls to try to find a way of dealing with lost circulation under pressure and to reveal the micro-mechanisms of fracture plugging to strengthen the borehole walls. By comprehensively considering the effects of the closure pressure of fractures on their openings during borehole wall strengthening, a set of experiment apparatus was developed and a method for evaluating the plugging of fractures with variable openings established. Used with the apparatus and the evaluation method, two quantitative evaluation indicators, which are maximum plugging differential pressure and equivalent plugging position, were proposed. Compared with the commonly used particle size matching criterion, using the revised normal distribution particle size matching criterion, the pressure bearing capacity of a borehole wall can be increased by 2.36 times at most. Equivalent plugging position is inversely proportional to pressure bearing capacity, and the revised normal distribution continuous particle size matching criterion can form at the entry of fractures a thin and dense plugging layer. Increase the strength of the plugging materials to a level as high as possible, the effect of the well pressure fluctuation can be reduced; increase the elasticity of the borehole wall strengthening plugging agents, the adaptability of the plugging layer to the dynamic fractures can be improved. Moreover, appropriately increasing the suspension stability of the plugging system and reasonably reducing its injection rate both are beneficial to the formation of the pressure bearing plugging layer and to the improvement of borehole wall strengthening.
Laboratory simulation study was conducted on the strengthening of borehole walls to try to find a way of dealing with lost circulation under pressure and to reveal the micro-mechanisms of fracture plugging to strengthen the borehole walls. By comprehensively considering the effects of the closure pressure of fractures on their openings during borehole wall strengthening, a set of experiment apparatus was developed and a method for evaluating the plugging of fractures with variable openings established. Used with the apparatus and the evaluation method, two quantitative evaluation indicators, which are maximum plugging differential pressure and equivalent plugging position, were proposed. Compared with the commonly used particle size matching criterion, using the revised normal distribution particle size matching criterion, the pressure bearing capacity of a borehole wall can be increased by 2.36 times at most. Equivalent plugging position is inversely proportional to pressure bearing capacity, and the revised normal distribution continuous particle size matching criterion can form at the entry of fractures a thin and dense plugging layer. Increase the strength of the plugging materials to a level as high as possible, the effect of the well pressure fluctuation can be reduced; increase the elasticity of the borehole wall strengthening plugging agents, the adaptability of the plugging layer to the dynamic fractures can be improved. Moreover, appropriately increasing the suspension stability of the plugging system and reasonably reducing its injection rate both are beneficial to the formation of the pressure bearing plugging layer and to the improvement of borehole wall strengthening.
2025, 42(3): 324-329.
doi: 10.12358/j.issn.1001-5620.2025.03.007
Abstract:
A high temperature calcium resistant plugging agent ZP-NPs has been developed based on the “anti-polyelectrolyte effect” theory to render water based drilling fluids high temperature stability, high calcium resistance and good plugging capacity. ZP-NPs is obtained by grafting zwitterionic polymer molecules onto the surfaces of nano silica. The microstructure of ZP-NPs was observed using infrared spectrum and electroscope, and the performance of ZP-NPs evaluated through dispersion test, filtration test and plugging test. It was found in these tests that ZP-NPs can stably disperse to nanoparticles/submicron particles for a long time in a high temperature high calcium chloride concentration (160℃, 11%CaCl2) solution. A base slurry, after being contaminated by high concentration calcium ions, has a high temperature high pressure (160℃, 3.5 MPa) filtration rate that does not exceed 20 mL, and the mud cakes obtained from the test are thin and tough. Fractures of 5 μm in width plugged by a bentonite slurry treated with ZP-NPs can stand pressures up to 5.5 MPa. The calcium resistant performance, plugging capacity and filtration control property of ZP-NPs were revealed through particle size analysis and EDS, and it was found that ZP-NPs has strong “anti-polyelectrolyte” effect; at high calcium concentrations, the particle sizes of ZP-NPs are still in nanometer size range, they can effectively shield the bentonite particles against the adsorption of calcium ions, thus maintaining the dispersion stability and excellent filtration control performance of a bentonite slurry at high calcium concentrations. This study provides a new theoretical and technical guidance for the development of new plugging agents with good calcium resistant capacity.
A high temperature calcium resistant plugging agent ZP-NPs has been developed based on the “anti-polyelectrolyte effect” theory to render water based drilling fluids high temperature stability, high calcium resistance and good plugging capacity. ZP-NPs is obtained by grafting zwitterionic polymer molecules onto the surfaces of nano silica. The microstructure of ZP-NPs was observed using infrared spectrum and electroscope, and the performance of ZP-NPs evaluated through dispersion test, filtration test and plugging test. It was found in these tests that ZP-NPs can stably disperse to nanoparticles/submicron particles for a long time in a high temperature high calcium chloride concentration (160℃, 11%CaCl2) solution. A base slurry, after being contaminated by high concentration calcium ions, has a high temperature high pressure (160℃, 3.5 MPa) filtration rate that does not exceed 20 mL, and the mud cakes obtained from the test are thin and tough. Fractures of 5 μm in width plugged by a bentonite slurry treated with ZP-NPs can stand pressures up to 5.5 MPa. The calcium resistant performance, plugging capacity and filtration control property of ZP-NPs were revealed through particle size analysis and EDS, and it was found that ZP-NPs has strong “anti-polyelectrolyte” effect; at high calcium concentrations, the particle sizes of ZP-NPs are still in nanometer size range, they can effectively shield the bentonite particles against the adsorption of calcium ions, thus maintaining the dispersion stability and excellent filtration control performance of a bentonite slurry at high calcium concentrations. This study provides a new theoretical and technical guidance for the development of new plugging agents with good calcium resistant capacity.
2025, 42(3): 330-337.
doi: 10.12358/j.issn.1001-5620.2025.03.008
Abstract:
Gel lost circulation materials (LCMs) presently in use have several shortcomings such as low strength, poor toughness and uncontrollable gelling time etc. A high gel strength composite nanomaterial and polymer gel LCM has been developed to overcome these shortcomings. The composite nanomaterial and polymer gel LCM is synthesized through physical-chemical crosslinking reaction with raw materials such as polyacrylamide (PAM) as the main gelling agents, nano silica as the strengthening agent, sodium carboxymethylcellulose (Na-CMC) as the viscosifier and phenolic resin as the crosslinking agent. In laboratory experiment, the optimum conditions for preparing the composite gel LCM were determined and the gelling performance, swelling capacity and fracture plugging capability of the composite gel LCM evaluated. The crosslinking mechanisms and fracture plugging mechanisms of the composite gel LCM were also analyzed. It was found through the experiment that the best composite gel LCM can be obtained in the following reaction conditions: 1.5%PAM, 3% nano silica, 0.6%Na-CMC, 1.5%crosslinking agent and temperature for the crosslinking is 150℃. The composite gel LCM obtained in these conditions has gel strength of 1,000 Pa, gel viscosity of 6×105 mPa∙s and gelling time of 2 hours. This composite gel LCM has good swelling performance and can be used to plug fractures of different sizes. An LCM slurry formulated with the composite gel LCM and an inert material, after being used to plug fractures of 1-4 mm in width, formed an LCM barrier across the fractures with pressure bearing capacity of 12 MPa (measured at 150℃ and after aging 48 hours). The composite gel LCM is easy to manufacture and cost effective, and can hopefully be used to solve severe mud loss problem encountered in drilling highly porous and fractured formations.
Gel lost circulation materials (LCMs) presently in use have several shortcomings such as low strength, poor toughness and uncontrollable gelling time etc. A high gel strength composite nanomaterial and polymer gel LCM has been developed to overcome these shortcomings. The composite nanomaterial and polymer gel LCM is synthesized through physical-chemical crosslinking reaction with raw materials such as polyacrylamide (PAM) as the main gelling agents, nano silica as the strengthening agent, sodium carboxymethylcellulose (Na-CMC) as the viscosifier and phenolic resin as the crosslinking agent. In laboratory experiment, the optimum conditions for preparing the composite gel LCM were determined and the gelling performance, swelling capacity and fracture plugging capability of the composite gel LCM evaluated. The crosslinking mechanisms and fracture plugging mechanisms of the composite gel LCM were also analyzed. It was found through the experiment that the best composite gel LCM can be obtained in the following reaction conditions: 1.5%PAM, 3% nano silica, 0.6%Na-CMC, 1.5%crosslinking agent and temperature for the crosslinking is 150℃. The composite gel LCM obtained in these conditions has gel strength of 1,000 Pa, gel viscosity of 6×105 mPa∙s and gelling time of 2 hours. This composite gel LCM has good swelling performance and can be used to plug fractures of different sizes. An LCM slurry formulated with the composite gel LCM and an inert material, after being used to plug fractures of 1-4 mm in width, formed an LCM barrier across the fractures with pressure bearing capacity of 12 MPa (measured at 150℃ and after aging 48 hours). The composite gel LCM is easy to manufacture and cost effective, and can hopefully be used to solve severe mud loss problem encountered in drilling highly porous and fractured formations.
2025, 42(3): 338-342.
doi: 10.12358/j.issn.1001-5620.2025.03.009
Abstract:
Lost circulation materials (LCMs), after being wetted by oil-based drilling fluids, have their sliding ability decreased and retention ability increased, causing them to be easy to flow back from the fractures through which the mud is lost and circulation is lost again. Using these LCMs, the success rates of lost circulation control are low. To improve the retention ability of the LCMs and the stability of the plugging layers, an oil absorbing viscous polymer MBS was developed. MBS is mainly composed of butadiene-styrene block copolymer BS and is formed by the coupling and grafting of inorganic minerals at a temperature between 70℃ and 90℃. The rate at which MBS absorbs oil and becomes viscous is controllable. At room temperature, the oil-absorbing rate of the polymer MBS is relatively low, and the viscosity of the LCM slurry is small, making the slurry preparation and pumping very convenient. At the temperature of a lost circulation zone, the oil-absorbing rate of the polymer MBS increases, and the viscosity of the LCM slurry becomes higher, making it convenient for the LCM slurry to be retained inside the fractures through which the mud is lost. Moreover, the inorganic minerals enhance their supporting effects on the LCM slurry. MBS can absorb oils that are 2.94 times of its volume. At a concentration of 5%, the viscosity of the LCM slurry increases, and the fluidity decreases by nearly 50%. When the concentration of MBS is 10%, it can be effectively retained in a smooth fracture with a width of 2 mm, and the pressures bearing capacities in the forward and reverse directions are 0.69 MPa and 0.53 MPa respectively. An LCMs slurry formulated with MBS and other commonly used LCMs was used in the well section of 2,900-3,130 m of the well Puluye XHF. The LCMs slurry effectively stabilized the pressure at 4.2 MPa, achieving the goal of controlling lost circulation and increasing the pressure bearing capacity of the formations. The lost circulation was controlled successfully in the first try.
Lost circulation materials (LCMs), after being wetted by oil-based drilling fluids, have their sliding ability decreased and retention ability increased, causing them to be easy to flow back from the fractures through which the mud is lost and circulation is lost again. Using these LCMs, the success rates of lost circulation control are low. To improve the retention ability of the LCMs and the stability of the plugging layers, an oil absorbing viscous polymer MBS was developed. MBS is mainly composed of butadiene-styrene block copolymer BS and is formed by the coupling and grafting of inorganic minerals at a temperature between 70℃ and 90℃. The rate at which MBS absorbs oil and becomes viscous is controllable. At room temperature, the oil-absorbing rate of the polymer MBS is relatively low, and the viscosity of the LCM slurry is small, making the slurry preparation and pumping very convenient. At the temperature of a lost circulation zone, the oil-absorbing rate of the polymer MBS increases, and the viscosity of the LCM slurry becomes higher, making it convenient for the LCM slurry to be retained inside the fractures through which the mud is lost. Moreover, the inorganic minerals enhance their supporting effects on the LCM slurry. MBS can absorb oils that are 2.94 times of its volume. At a concentration of 5%, the viscosity of the LCM slurry increases, and the fluidity decreases by nearly 50%. When the concentration of MBS is 10%, it can be effectively retained in a smooth fracture with a width of 2 mm, and the pressures bearing capacities in the forward and reverse directions are 0.69 MPa and 0.53 MPa respectively. An LCMs slurry formulated with MBS and other commonly used LCMs was used in the well section of 2,900-3,130 m of the well Puluye XHF. The LCMs slurry effectively stabilized the pressure at 4.2 MPa, achieving the goal of controlling lost circulation and increasing the pressure bearing capacity of the formations. The lost circulation was controlled successfully in the first try.
2025, 42(3): 343-349.
doi: 10.12358/j.issn.1001-5620.2025.03.010
Abstract:
The exploration and development of deep coalbed methane have opened up a new field of developing resources in new formations in the Ordos Basin, ensuring the steady growth of the oil and gas equivalent of the Changqing oilfield. However, due to the deep burial of the target layers and the long open hole section of the upper part, the difficulty of drilling and development has increased significantly. It is mainly manifested in technical problems such as the prominent contradiction between borehole wall collapse and lost circulation in the second interval, the low success rate of lost circulation control in the first try in the second interval Ф311.2 mm borehole, and the instability and collapse of the coal-seam borehole walls in the horizontal section. To deal with these problems, the casing program was optimized, thereby separating the borehole wall collapse and lost circulation in different intervals. Two sets of drilling fluids were developed to ensure the stability of the wellbore. An efficient technology was adopted to improve the efficiency of lost circulation control without tripping drill strings out of hole. Meanwhile key technical measures were implemented, forming a set of lost circulation prevention and control technology suitable for deep coalbed methane development in the eastern part of the Ordos Basin. This technology has been applied on more than 10 wells, and the drilling time has been reduced by 36.5%. This technology has been used to successfully drill the longest horizontal section of 2,222 m, contributing to the deep coalbed methane development in China.
The exploration and development of deep coalbed methane have opened up a new field of developing resources in new formations in the Ordos Basin, ensuring the steady growth of the oil and gas equivalent of the Changqing oilfield. However, due to the deep burial of the target layers and the long open hole section of the upper part, the difficulty of drilling and development has increased significantly. It is mainly manifested in technical problems such as the prominent contradiction between borehole wall collapse and lost circulation in the second interval, the low success rate of lost circulation control in the first try in the second interval Ф311.2 mm borehole, and the instability and collapse of the coal-seam borehole walls in the horizontal section. To deal with these problems, the casing program was optimized, thereby separating the borehole wall collapse and lost circulation in different intervals. Two sets of drilling fluids were developed to ensure the stability of the wellbore. An efficient technology was adopted to improve the efficiency of lost circulation control without tripping drill strings out of hole. Meanwhile key technical measures were implemented, forming a set of lost circulation prevention and control technology suitable for deep coalbed methane development in the eastern part of the Ordos Basin. This technology has been applied on more than 10 wells, and the drilling time has been reduced by 36.5%. This technology has been used to successfully drill the longest horizontal section of 2,222 m, contributing to the deep coalbed methane development in China.
2016, 33(1): 6-10.
doi: 10.3969/j.issn.1001-5620.2016.01.002
摘要：
以妥尔油脂肪酸和马来酸酐为主要原料合成了一种油基钻井液抗高温主乳化剂HT-MUL,并确定了妥尔油脂肪酸单体的最佳酸值及马来酸酐单体的最优加量。对HT-MUL进行了单剂评价,结果表明HT-MUL的乳化能力良好,配制的油水比为60:40的油包水乳液的破乳电压最高可达490 V,90:10的乳液破乳电压最高可达1000 V。从抗温性、滤失性、乳化率方面对HT-MUL和国内外同类产品进行了对比,结果表明HT-MUL配制的乳液破乳电压更大、滤失量更小、乳化率更高,整体性能优于国内外同类产品。应用主乳化剂HT-MUL配制了高密度的油基钻井液,其性能评价表明体系的基本性能良好,在220℃高温热滚后、破乳电压高达800 V,滤失量低于5 mL。HT-MUL配制的油基钻井液具有良好的抗高温性和乳化稳定性。
以妥尔油脂肪酸和马来酸酐为主要原料合成了一种油基钻井液抗高温主乳化剂HT-MUL,并确定了妥尔油脂肪酸单体的最佳酸值及马来酸酐单体的最优加量。对HT-MUL进行了单剂评价,结果表明HT-MUL的乳化能力良好,配制的油水比为60:40的油包水乳液的破乳电压最高可达490 V,90:10的乳液破乳电压最高可达1000 V。从抗温性、滤失性、乳化率方面对HT-MUL和国内外同类产品进行了对比,结果表明HT-MUL配制的乳液破乳电压更大、滤失量更小、乳化率更高,整体性能优于国内外同类产品。应用主乳化剂HT-MUL配制了高密度的油基钻井液,其性能评价表明体系的基本性能良好,在220℃高温热滚后、破乳电压高达800 V,滤失量低于5 mL。HT-MUL配制的油基钻井液具有良好的抗高温性和乳化稳定性。
2016, 33(5): 1-8.
doi: 10.3969/j.issn.1001-5620.2016.05.001
摘要：
综述了国内外页岩气井井壁失稳机理、稳定井壁主要方法及水基钻井液技术研究与应用现状，讨论了当前中国页岩气井钻井液技术面临的主要技术难题，分析了美国页岩气井与中国主要页岩气产区井壁失稳机理的差异，指出了中国页岩气井水基钻井液技术研究存在的误区与不足，提出了中国页岩气井水基钻井液技术发展方向。
综述了国内外页岩气井井壁失稳机理、稳定井壁主要方法及水基钻井液技术研究与应用现状，讨论了当前中国页岩气井钻井液技术面临的主要技术难题，分析了美国页岩气井与中国主要页岩气产区井壁失稳机理的差异，指出了中国页岩气井水基钻井液技术研究存在的误区与不足，提出了中国页岩气井水基钻井液技术发展方向。
2018, 35(2): 1-16.
doi: 10.3969/j.issn.1001-5620.2018.02.001
摘要：
通常在勘探开发油气过程中会发生不同程度的油气层损害，导致产量下降、甚至"枪毙"油气层等，钻井液是第一个与油气层相接触的外来流体，引起的油气层损害程度往往较大。为减轻或避免钻井液导致的油气层损害、提高单井产量，国内外学者们进行了长达半个世纪以上的研究工作，先后建立了"屏蔽暂堵、精细暂堵、物理化学膜暂堵"三代暂堵型保护油气层钻井液技术，使保护油气层效果逐步提高，经济效益明显。但是，与石油工程师们追求的"超低"损害目标仍存在一定差距，特别是随着非常规、复杂、超深层、超深水等类型油气层勘探开发力度的加大，以前的保护技术难以满足要求。为此，将仿生学引入保护油气层钻井液理论中，发展了适合不同油气层渗透率大小的"超双疏、生物膜、协同增效"仿生技术，并在各大油田得到推广应用，达到了"超低"损害目标，标志着第四代暂堵型保护油气层钻井液技术的建立。对上述4代暂堵型保护油气层技术的理论基础、实施方案、室内评价、现场应用效果与优缺点等进行了论述，并通过梳理阐明了将来的研究方向与发展趋势，对现场技术人员和科技工作者具有较大指导意义。
通常在勘探开发油气过程中会发生不同程度的油气层损害，导致产量下降、甚至"枪毙"油气层等，钻井液是第一个与油气层相接触的外来流体，引起的油气层损害程度往往较大。为减轻或避免钻井液导致的油气层损害、提高单井产量，国内外学者们进行了长达半个世纪以上的研究工作，先后建立了"屏蔽暂堵、精细暂堵、物理化学膜暂堵"三代暂堵型保护油气层钻井液技术，使保护油气层效果逐步提高，经济效益明显。但是，与石油工程师们追求的"超低"损害目标仍存在一定差距，特别是随着非常规、复杂、超深层、超深水等类型油气层勘探开发力度的加大，以前的保护技术难以满足要求。为此，将仿生学引入保护油气层钻井液理论中，发展了适合不同油气层渗透率大小的"超双疏、生物膜、协同增效"仿生技术，并在各大油田得到推广应用，达到了"超低"损害目标，标志着第四代暂堵型保护油气层钻井液技术的建立。对上述4代暂堵型保护油气层技术的理论基础、实施方案、室内评价、现场应用效果与优缺点等进行了论述，并通过梳理阐明了将来的研究方向与发展趋势，对现场技术人员和科技工作者具有较大指导意义。
2016, 33(1): 33-36.
doi: 10.3969/j.issn.1001-5620.2016.01.007
摘要：
页岩具有极低的渗透率和极小的孔喉尺寸,传统封堵剂难以在页岩表面形成有效的泥饼,只有纳米级颗粒才能封堵页岩的孔喉,阻止液相侵入地层,维持井壁稳定,保护储层。以苯乙烯(St)、甲基丙烯酸甲酯(MMA)为单体,过硫酸钾(KPS)为引发剂,采用乳液聚合法制备了纳米聚合物微球封堵剂SD-seal。通过红外光谱、透射电镜、热重分析和激光粒度分析对产物进行了表征,通过龙马溪组岩样的压力传递实验研究了其封堵性能。结果表明,SD-seal纳米粒子分散性好,形状规则(基本为球形),粒度较均匀(20 nm左右),分解温度高达402.5℃,热稳定性好,阻缓压力传递效果显著,使龙马溪组页岩岩心渗透率降低95%。
页岩具有极低的渗透率和极小的孔喉尺寸,传统封堵剂难以在页岩表面形成有效的泥饼,只有纳米级颗粒才能封堵页岩的孔喉,阻止液相侵入地层,维持井壁稳定,保护储层。以苯乙烯(St)、甲基丙烯酸甲酯(MMA)为单体,过硫酸钾(KPS)为引发剂,采用乳液聚合法制备了纳米聚合物微球封堵剂SD-seal。通过红外光谱、透射电镜、热重分析和激光粒度分析对产物进行了表征,通过龙马溪组岩样的压力传递实验研究了其封堵性能。结果表明,SD-seal纳米粒子分散性好,形状规则(基本为球形),粒度较均匀(20 nm左右),分解温度高达402.5℃,热稳定性好,阻缓压力传递效果显著,使龙马溪组页岩岩心渗透率降低95%。
2016, 33(4): 74-78.
doi: 10.3969/j.issn.1001-5620.2016.04.015
摘要：
利用自主研发的水泥环密封性实验装置研究了套管内加卸压循环作用下水泥环的密封性，根据实验结果得出了循环应力作用下水泥环密封性失效的机理。实验结果显示，在较低套管内压循环作用下，水泥环保持密封性所能承受的应力循环次数较多；在较高循环应力作用下，水泥环密封性失效时循环次数较少。表明在套管内较低压力作用下，水泥环所受的应力较低，应力水平处于弹性状态，在加卸载的循环作用下，水泥环可随之弹性变形和弹性恢复；在较高应力作用下，水泥环内部固有的微裂纹和缺陷逐渐扩展和连通，除了发生弹性变形还产生了塑性变形；随着应力循环次数的增加，塑性变形也不断地累积。循环压力卸载时，套管弹性回缩而水泥环塑性变形不可完全恢复，2者在界面处的变形不协调而引起拉应力。当拉应力超过界面处的胶结强度时出现微环隙，导致水泥环密封性失效，水泥环发生循环应力作用的低周期密封性疲劳破坏。套管内压力越大，水泥环中产生的应力水平越高，产生的塑性变形越大，每次卸载时产生的残余应变和界面处拉应力也越大，因此引起密封性失效的应力循环次数越少。
利用自主研发的水泥环密封性实验装置研究了套管内加卸压循环作用下水泥环的密封性，根据实验结果得出了循环应力作用下水泥环密封性失效的机理。实验结果显示，在较低套管内压循环作用下，水泥环保持密封性所能承受的应力循环次数较多；在较高循环应力作用下，水泥环密封性失效时循环次数较少。表明在套管内较低压力作用下，水泥环所受的应力较低，应力水平处于弹性状态，在加卸载的循环作用下，水泥环可随之弹性变形和弹性恢复；在较高应力作用下，水泥环内部固有的微裂纹和缺陷逐渐扩展和连通，除了发生弹性变形还产生了塑性变形；随着应力循环次数的增加，塑性变形也不断地累积。循环压力卸载时，套管弹性回缩而水泥环塑性变形不可完全恢复，2者在界面处的变形不协调而引起拉应力。当拉应力超过界面处的胶结强度时出现微环隙，导致水泥环密封性失效，水泥环发生循环应力作用的低周期密封性疲劳破坏。套管内压力越大，水泥环中产生的应力水平越高，产生的塑性变形越大，每次卸载时产生的残余应变和界面处拉应力也越大，因此引起密封性失效的应力循环次数越少。
2017, 34(1): 1-8.
doi: 10.3969/j.issn.1001-5620.2017.01.001
摘要：
分析了硬脆性泥页岩井壁失稳的原因，介绍了纳米材料特点及其应用，并概述了国内外钻井液用纳米封堵剂的研究进展，包括有机纳米封堵剂、无机纳米封堵剂、有机/无机纳米封堵剂，以及纳米封堵剂现场应用案例。笔者认为：利用无机纳米材料刚性特征以及有机聚合物可任意变形、支化成膜等特性，形成的一种核壳结构的无机/聚合物类纳米封堵剂，能够很好地分散到钻井液中，且对钻井液黏度和切力影响较小，这种类型的纳米封堵剂能够在低浓度下封堵泥页岩孔喉，建立一种疏水型且具有一定强度的泥页岩人工井壁，这不仅能够阻止钻井液侵入，而且还能提高地层承压能力，无机纳米材料与有机聚合物的结合是未来钻井液防塌剂的发展方向。
分析了硬脆性泥页岩井壁失稳的原因，介绍了纳米材料特点及其应用，并概述了国内外钻井液用纳米封堵剂的研究进展，包括有机纳米封堵剂、无机纳米封堵剂、有机/无机纳米封堵剂，以及纳米封堵剂现场应用案例。笔者认为：利用无机纳米材料刚性特征以及有机聚合物可任意变形、支化成膜等特性，形成的一种核壳结构的无机/聚合物类纳米封堵剂，能够很好地分散到钻井液中，且对钻井液黏度和切力影响较小，这种类型的纳米封堵剂能够在低浓度下封堵泥页岩孔喉，建立一种疏水型且具有一定强度的泥页岩人工井壁，这不仅能够阻止钻井液侵入，而且还能提高地层承压能力，无机纳米材料与有机聚合物的结合是未来钻井液防塌剂的发展方向。
2016, 33(6): 121-126.
doi: 10.3969/j.issn.1001-5620.2016.06.022
摘要：
统计长庆油田罗*区块2015年存地液量与油井一年累积产量的关系发现，存地液量越大，一年累积产量越高，与常规的返排率越高产量越高概念恰恰相反，可能与存地液的自发渗吸替油有关。核磁实验结果表明，渗吸替油不同于驱替作用，渗吸过程中小孔隙对采出程度贡献大，而驱替过程中大孔隙对采出程度贡献大，但从现场致密储层岩心孔隙度来看，储层驱替效果明显弱于渗吸效果。通过实验研究了影响自发渗吸效率因素，探索影响压裂液油水置换的关键影响因素，得出了最佳渗吸采出率及最大渗吸速度现场参数。结果表明，各参数对渗吸速度的影响顺序为：界面张力 > 渗透率 > 原油黏度 > 矿化度,岩心渗透率越大，渗吸采收率越大，但是增幅逐渐减小；原油黏度越小，渗吸采收率越大；渗吸液矿化度越大，渗吸采收率越大；当渗吸液中助排剂浓度在0.005%~5%，即界面张力在0.316~10.815 mN/m范围内时，浓度为0.5%（界面张力为0.869 mN/m）的渗吸液可以使渗吸采收率达到最大。静态渗吸结果表明：并不是界面张力越低，采收率越高，而是存在某一最佳界面张力，使地层中被绕流油的数量减少，渗吸采收率达到最高，为油田提高致密储层采收率提供实验指导。
统计长庆油田罗*区块2015年存地液量与油井一年累积产量的关系发现，存地液量越大，一年累积产量越高，与常规的返排率越高产量越高概念恰恰相反，可能与存地液的自发渗吸替油有关。核磁实验结果表明，渗吸替油不同于驱替作用，渗吸过程中小孔隙对采出程度贡献大，而驱替过程中大孔隙对采出程度贡献大，但从现场致密储层岩心孔隙度来看，储层驱替效果明显弱于渗吸效果。通过实验研究了影响自发渗吸效率因素，探索影响压裂液油水置换的关键影响因素，得出了最佳渗吸采出率及最大渗吸速度现场参数。结果表明，各参数对渗吸速度的影响顺序为：界面张力 > 渗透率 > 原油黏度 > 矿化度,岩心渗透率越大，渗吸采收率越大，但是增幅逐渐减小；原油黏度越小，渗吸采收率越大；渗吸液矿化度越大，渗吸采收率越大；当渗吸液中助排剂浓度在0.005%~5%，即界面张力在0.316~10.815 mN/m范围内时，浓度为0.5%（界面张力为0.869 mN/m）的渗吸液可以使渗吸采收率达到最大。静态渗吸结果表明：并不是界面张力越低，采收率越高，而是存在某一最佳界面张力，使地层中被绕流油的数量减少，渗吸采收率达到最高，为油田提高致密储层采收率提供实验指导。
2016, 33(1): 17-21.
doi: 10.3969/j.issn.1001-5620.2016.01.004
摘要：
目前中国页岩气水平井定向段及水平段钻井均使用油基钻井液,但油基岩屑处理费用昂贵,急需开发和应用一种具有环境保护特性的高性能水基钻井液体系。介绍了2种高性能水基钻井液体系的室内实验和现场试验效果。在长宁H9-4井水平段、长宁H9-3和长宁H9-5井定向至完井段试验了GOF高性能水基钻井液体系,该体系采用的是聚合物封堵抑制方案,完全采用水基润滑方式;在昭通区块YS108H4-2井水平段试验了高润强抑制性水基钻井液体系,该体系采用的是有机、无机盐复合防膨方案以及润滑剂与柴油复合润滑方式。现场应用表明,定向段机械钻速提高50%~75%,水平段机械钻速提高75%~100%。通过实验数据及现场使用情况,对比分析了2种体系的优劣,找出了他们各自存在的问题,并提出了改进的思路,为高性能水基钻井液的进一步完善提供一些经验。
目前中国页岩气水平井定向段及水平段钻井均使用油基钻井液,但油基岩屑处理费用昂贵,急需开发和应用一种具有环境保护特性的高性能水基钻井液体系。介绍了2种高性能水基钻井液体系的室内实验和现场试验效果。在长宁H9-4井水平段、长宁H9-3和长宁H9-5井定向至完井段试验了GOF高性能水基钻井液体系,该体系采用的是聚合物封堵抑制方案,完全采用水基润滑方式;在昭通区块YS108H4-2井水平段试验了高润强抑制性水基钻井液体系,该体系采用的是有机、无机盐复合防膨方案以及润滑剂与柴油复合润滑方式。现场应用表明,定向段机械钻速提高50%~75%,水平段机械钻速提高75%~100%。通过实验数据及现场使用情况,对比分析了2种体系的优劣,找出了他们各自存在的问题,并提出了改进的思路,为高性能水基钻井液的进一步完善提供一些经验。
2020, 37(1): 1-8.
doi: 10.3969/j.issn.1001-5620.2020.01.001
摘要：
废弃钻井液污染大、种类多、处理难，给水质和土壤环境带来巨大的负面影响，随着近些年环保法规的日益完善，对废弃钻井液的处理技术也提出了新要求。概述了9种不同处理方法及其发展现状，重点分析了固化法、热解吸法、化学强化固液分离法、不落地技术和多种技术联用等处理技术，并对几种现行的主流处理技术进行了对比，指出了各类方法的发展前景，得出多种技术联用具有较好的发展潜力。分析认为今后的研究方向与热点在于如何低能耗、高效率地实现对废弃钻井液的资源化处理，具体工作既要包含污染物的源头、过程和结果控制，也要加强管理和相关制度的建立，综合开发新技术。
废弃钻井液污染大、种类多、处理难，给水质和土壤环境带来巨大的负面影响，随着近些年环保法规的日益完善，对废弃钻井液的处理技术也提出了新要求。概述了9种不同处理方法及其发展现状，重点分析了固化法、热解吸法、化学强化固液分离法、不落地技术和多种技术联用等处理技术，并对几种现行的主流处理技术进行了对比，指出了各类方法的发展前景，得出多种技术联用具有较好的发展潜力。分析认为今后的研究方向与热点在于如何低能耗、高效率地实现对废弃钻井液的资源化处理，具体工作既要包含污染物的源头、过程和结果控制，也要加强管理和相关制度的建立，综合开发新技术。
2016, 33(3): 25-29.
doi: 10.3969/j.issn.1001-5620.2016.03.005
摘要：
页岩气井水平井段井壁失稳是目前中国页岩气资源勘探开发的关键技术难题。通过云南昭通108区块龙马溪组页岩的X-射线衍射分析、扫描电镜（SEM）观察、力学特性分析、润湿性、膨胀率及回收率等实验，研究了其矿物组成、微观组构特征、表面性能、膨胀和分散特性，揭示了云南昭通108区块龙马溪组页岩地层井壁水化失稳机理。该地层黏土矿物以伊利石为主要组分，不含蒙脱石及伊蒙混层，表面水化是引起页岩地层井壁失稳的主要原因。基于热力学第二定律，利用降低页岩表面自由能以抑制页岩表面水化的原理，建立了通过多碳醇吸附作用改变页岩润湿性，有效降低其表面自由能、抑制表面水化，进而显著抑制页岩水化膨胀和分散的稳定井壁方法。
页岩气井水平井段井壁失稳是目前中国页岩气资源勘探开发的关键技术难题。通过云南昭通108区块龙马溪组页岩的X-射线衍射分析、扫描电镜（SEM）观察、力学特性分析、润湿性、膨胀率及回收率等实验，研究了其矿物组成、微观组构特征、表面性能、膨胀和分散特性，揭示了云南昭通108区块龙马溪组页岩地层井壁水化失稳机理。该地层黏土矿物以伊利石为主要组分，不含蒙脱石及伊蒙混层，表面水化是引起页岩地层井壁失稳的主要原因。基于热力学第二定律，利用降低页岩表面自由能以抑制页岩表面水化的原理，建立了通过多碳醇吸附作用改变页岩润湿性，有效降低其表面自由能、抑制表面水化，进而显著抑制页岩水化膨胀和分散的稳定井壁方法。
2020, 37(6): 685-693.
doi: 10.3969/j.issn.1001-5620.2020.06.002
Abstract:
2016, 33(5): 1-8.
doi: 10.3969/j.issn.1001-5620.2016.05.001
Abstract:
2016, 33(6): 1-9.
doi: 10.3969/j.issn.1001-5620.2016.06.001
Abstract:
2017, 34(1): 1-8.
doi: 10.3969/j.issn.1001-5620.2017.01.001
Abstract:
2016, 33(6): 45-50.
doi: 10.3969/j.issn.1001-5620.2016.06.008
Abstract:
2016, 33(1): 6-10.
doi: 10.3969/j.issn.1001-5620.2016.01.002
Abstract:
2018, 35(1): 101-104.
doi: 10.3969/j.issn.1001-5620.2018.01.019
Abstract:
2017, 34(1): 16-22.
doi: 10.3969/j.issn.1001-5620.2017.01.003
Abstract:
2018, 35(1): 34-37.
doi: 10.3969/j.issn.1001-5620.2018.01.006
Abstract:
2016, 33(6): 10-16.
doi: 10.3969/j.issn.1001-5620.2016.06.002
Abstract:
Governed by：
China National Petroleum Corporation Ltd
China National Petroleum Corporation Ltd
Sponsored by：
CNPC Bohai Drilling Engineering Co. LtdPetroChina Huabei Oilfield Company
CNPC Bohai Drilling Engineering Co. LtdPetroChina Huabei Oilfield Company
Editor-in-Chief：Shi-chun Chen（Engineer Technology Research Institute,BHDC）
Deputy Editor-in-chief：
Gui-juan Wang（Engineer Technology Research Institute,BHDC）Qiang Ren（Engineer Technology Research Institute,BHDC）
Address：
Editorial Office of Drilling Fluid and Completion Fluid, Bohai Drilling Engineering Institute, Yanshan South Road, Renqiu City, Hebei Province
Editorial Office of Drilling Fluid and Completion Fluid, Bohai Drilling Engineering Institute, Yanshan South Road, Renqiu City, Hebei Province
Postcode： 062552
Tel：（0317）2725487 2722354
E-mail： zjyywjy@126.com
CN 12-1486/TE
ISSN 1001-5620
