Due to strong non-linearities in the diffusivity equation, numerically-assisted rate-transient analysis (RTA) techniques have been suggested for analysis of multi-phase production data from multi-fractured horizontal wells (MFHWs). However, these methods are based on some limiting assumptions that cannot be generalized for three-phase flow or when relative permeability is unknown. In this study, a new RTA-assisted history-matching technique is proposed to simultaneously match production data and diagnostic plots during the calibration process. In the proposed method, the objective function is modified to include the derivative of the integral of rate-normalized pressure for the primary phases. As such, in the history-matching process using compositional numerical simulation, the flow regimes are also matched, which can increase the reliability of the calibrated numerical model. This approach is applied to a challenging dataset: production data from a MFHW completed in a Canadian shale reservoir hosting a near-critical gas condensate fluid. The calibrated model is then applied to co-optimize CO2 storage and oil production using a cyclic gas injection scheme. The results demonstrate that when the modified objective function is used, the history-matching scheme will reject models that cannot reproduce the flow regimes even if the production data are visually matched. Another benefit of this modified history-matching workflow is that, unlike other numerically-assisted RTA techniques, it is not limited to any specific conceptual model or reservoir geometry. Further, interactions between parameters are accounted for during the calibration process. Co-optimization using the calibrated model leads to an optimized Huff-n-Puff (HnP) design that can produce 40% additional (incremental) oil, while around 17% of the injected CO2 is stored during the cyclic CO2 injection process. In this study, a modified objective function is introduced for the first time to enhance the numerical history-matching process to ensure the resulting calibrated model can also reproduce the observed transient flow regimes. This approach is easy to implement and is not limited to a specific model geometry or any input-output relationship.
{"title":"RTA-Assisted Numerical History-Matching and Co-Optimization of CO2 Storage and HnP Performance for a Near Critical Gas Condensate Shale Well","authors":"H. Hamdi, C. Clarkson, A. Ghanizadeh","doi":"10.2118/210224-ms","DOIUrl":"https://doi.org/10.2118/210224-ms","url":null,"abstract":"\u0000 Due to strong non-linearities in the diffusivity equation, numerically-assisted rate-transient analysis (RTA) techniques have been suggested for analysis of multi-phase production data from multi-fractured horizontal wells (MFHWs). However, these methods are based on some limiting assumptions that cannot be generalized for three-phase flow or when relative permeability is unknown. In this study, a new RTA-assisted history-matching technique is proposed to simultaneously match production data and diagnostic plots during the calibration process.\u0000 In the proposed method, the objective function is modified to include the derivative of the integral of rate-normalized pressure for the primary phases. As such, in the history-matching process using compositional numerical simulation, the flow regimes are also matched, which can increase the reliability of the calibrated numerical model. This approach is applied to a challenging dataset: production data from a MFHW completed in a Canadian shale reservoir hosting a near-critical gas condensate fluid. The calibrated model is then applied to co-optimize CO2 storage and oil production using a cyclic gas injection scheme.\u0000 The results demonstrate that when the modified objective function is used, the history-matching scheme will reject models that cannot reproduce the flow regimes even if the production data are visually matched. Another benefit of this modified history-matching workflow is that, unlike other numerically-assisted RTA techniques, it is not limited to any specific conceptual model or reservoir geometry. Further, interactions between parameters are accounted for during the calibration process. Co-optimization using the calibrated model leads to an optimized Huff-n-Puff (HnP) design that can produce 40% additional (incremental) oil, while around 17% of the injected CO2 is stored during the cyclic CO2 injection process.\u0000 In this study, a modified objective function is introduced for the first time to enhance the numerical history-matching process to ensure the resulting calibrated model can also reproduce the observed transient flow regimes. This approach is easy to implement and is not limited to a specific model geometry or any input-output relationship.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123333779","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This work was carried out to compare a new system with synthetic polyacrylamide friction reducers used in the oil and gas industry. The most common friction reducers used for fracturing are anionic, and hence have limited use in high TDS brines especially in brines containing di and trivalent metal ions. When the new system is properly optimized, we were able to achieve a very efficient and low-cost carrier fluid that can give maximum friction reduction and effectively suspend proppant during a fracturing treatment. The new technology for unconventional fracturing is a versatile and multifunctional product that can be pumped with the traditional frac equipment used in the industry for pumping powdered dry guar gum on the fly. The main objective of this work is to develop a new friction reducer formulation to aim to reduce cost and improve retained conductivity. This product is shown to be Gulf of Mexico green and biodegradable. Conventional breakers can be used to break these fluids and give excellent retained permeability on cores. The new system gives good friction reduction even at a very small dosage of 1ppt to 4ppt or 0.25-1.0 gpt, and it can be used similarly to guar gum as a linear gel or can be crosslinked with boron to yield better viscosity and proppant transport. The presence of iron in water can seriously affect the rheology and friction of traditional friction reducers, high viscosity friction reducers, and even guar systems. Laboratory studies have shown that this new product is very effective even in water containing very high concentrations of Ferric iron. Case histories from wells treated with this system containing high divalent and trivalent metal ions confirm the laboratory findings. In countries where equipment to pump on the fly is not available, the new system can be used as a slurry also. This paper will present laboratory test results of using a new polysaccharide friction reducer with similar friction reduction to a Polyacrylamide Friction reducer and the proppant suspension of a crosslinked guar system. This system can be used with fresh or saline waters containing high concentrations of divalent and trivalent metal ions. This gives the operator the flexibility of using any water, and the water analysis step before a frac job can be eliminated.
{"title":"A Novel Polysaccharide Friction Reducer That can be Used with Water of All Salinity Levels","authors":"Farhan Siddiqui, A. Emrani","doi":"10.2118/210207-ms","DOIUrl":"https://doi.org/10.2118/210207-ms","url":null,"abstract":"\u0000 This work was carried out to compare a new system with synthetic polyacrylamide friction reducers used in the oil and gas industry. The most common friction reducers used for fracturing are anionic, and hence have limited use in high TDS brines especially in brines containing di and trivalent metal ions. When the new system is properly optimized, we were able to achieve a very efficient and low-cost carrier fluid that can give maximum friction reduction and effectively suspend proppant during a fracturing treatment.\u0000 The new technology for unconventional fracturing is a versatile and multifunctional product that can be pumped with the traditional frac equipment used in the industry for pumping powdered dry guar gum on the fly. The main objective of this work is to develop a new friction reducer formulation to aim to reduce cost and improve retained conductivity. This product is shown to be Gulf of Mexico green and biodegradable. Conventional breakers can be used to break these fluids and give excellent retained permeability on cores. The new system gives good friction reduction even at a very small dosage of 1ppt to 4ppt or 0.25-1.0 gpt, and it can be used similarly to guar gum as a linear gel or can be crosslinked with boron to yield better viscosity and proppant transport. The presence of iron in water can seriously affect the rheology and friction of traditional friction reducers, high viscosity friction reducers, and even guar systems. Laboratory studies have shown that this new product is very effective even in water containing very high concentrations of Ferric iron. Case histories from wells treated with this system containing high divalent and trivalent metal ions confirm the laboratory findings. In countries where equipment to pump on the fly is not available, the new system can be used as a slurry also.\u0000 This paper will present laboratory test results of using a new polysaccharide friction reducer with similar friction reduction to a Polyacrylamide Friction reducer and the proppant suspension of a crosslinked guar system. This system can be used with fresh or saline waters containing high concentrations of divalent and trivalent metal ions. This gives the operator the flexibility of using any water, and the water analysis step before a frac job can be eliminated.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128719934","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
G. Zhan, N. Lyons, Msalli Al Otaibi, D. He, Andrew L. Robertson
Since the late 1970's, research on the efficiency and cutting life of polycrystalline diamond compact (PDC) cutters identified elevated temperature due to frictional heating as one of the primary accelerants of wear to the diamond cutting edge. Temperatures as low as 700 °C activate the back-conversion process, whereby diamond transforms into graphite, due to the presence of catalytic metal in the diamond structure. The Oil and Gas industry responded by investing years developing technologies to reduce the temperatures that PDC's experience in application via improved hydraulics for cooling, higher quality surface finishes to reduce friction, and improved thermal stability via material structure and chemical treatments. PDC cutter technology has progressed substantially in the last 30+ years, but the challenge of synthesizing a perfectly thermally stable PDC still remains unmet until now. Recently, Zhan (2018, 2020, 2021a and 2021b) first developed a new strategy to synthesize ultrastrong and catalyst-free polycrystalline diamond (CFPCD) or binderless PDC cutters with a new world record as the hardest and tough diamond material and the highest thermal stability up to 1,400°C via his invented ultra-high pressure and ultra-high temperature (UHPHT) technology, which is three to seven times higher than conventional PDC cutters used in the industry. An initial laboratory study of a new catalyst-free extreme high pressure, high temperature CFPCD material provides the first instance of a catalyst metal free polycrystalline diamond structure that actually boosts rock cutting performance above and beyond that of the current state-of-the-art PDCs. Proof of concept CFPCD specimens were evaluated against commercial, state-of-the-art non-leached (NL) and deep leached (DL) PDC cutters in the lab. Two CFPCD grades, A & B, were run through a series of tests to evaluate their potential for rock cutting and, ultimately, for use in oil & gas drilling applications. Laboratory testing was conducted on vertical borer wear tests, KIC fracture toughness tests, and thermal degradation monitoring tests. Lab results reveal a threshold that must be exceeded in the synthesis of catalyst-free CFPCDs to achieve sufficient diamond intergrowth and structural integrity to surpass the current state-of-the-art DL PDCs. CFPCD grade A wore equivalently to a commercially available NL cutter and exhibited a toughness comparable to that of commercially available DL PDC material. Grade B, synthesized at a significantly higher pressure than grade A, cut 5.7 times the distance of a commercial NL PDC for an equivalent wearscar volume, and exhibited a 160 % reduction in wear volume comparing volume of diamond worn to volume of rock cut (or G ratios) to DL PDC after cutting the equivalent of roughly 50 miles of rock. The wearscar surface of Grade B also exhibited excellent integrity with no cracking or chipping damage compared to Grade A and commercial PDC grades. This is the first docume
{"title":"A First Look at 100% Thermally Stable Polycrystalline Diamond (PCD) for Oil & Gas Drilling","authors":"G. Zhan, N. Lyons, Msalli Al Otaibi, D. He, Andrew L. Robertson","doi":"10.2118/210352-ms","DOIUrl":"https://doi.org/10.2118/210352-ms","url":null,"abstract":"\u0000 Since the late 1970's, research on the efficiency and cutting life of polycrystalline diamond compact (PDC) cutters identified elevated temperature due to frictional heating as one of the primary accelerants of wear to the diamond cutting edge. Temperatures as low as 700 °C activate the back-conversion process, whereby diamond transforms into graphite, due to the presence of catalytic metal in the diamond structure. The Oil and Gas industry responded by investing years developing technologies to reduce the temperatures that PDC's experience in application via improved hydraulics for cooling, higher quality surface finishes to reduce friction, and improved thermal stability via material structure and chemical treatments. PDC cutter technology has progressed substantially in the last 30+ years, but the challenge of synthesizing a perfectly thermally stable PDC still remains unmet until now. Recently, Zhan (2018, 2020, 2021a and 2021b) first developed a new strategy to synthesize ultrastrong and catalyst-free polycrystalline diamond (CFPCD) or binderless PDC cutters with a new world record as the hardest and tough diamond material and the highest thermal stability up to 1,400°C via his invented ultra-high pressure and ultra-high temperature (UHPHT) technology, which is three to seven times higher than conventional PDC cutters used in the industry. An initial laboratory study of a new catalyst-free extreme high pressure, high temperature CFPCD material provides the first instance of a catalyst metal free polycrystalline diamond structure that actually boosts rock cutting performance above and beyond that of the current state-of-the-art PDCs.\u0000 Proof of concept CFPCD specimens were evaluated against commercial, state-of-the-art non-leached (NL) and deep leached (DL) PDC cutters in the lab. Two CFPCD grades, A & B, were run through a series of tests to evaluate their potential for rock cutting and, ultimately, for use in oil & gas drilling applications. Laboratory testing was conducted on vertical borer wear tests, KIC fracture toughness tests, and thermal degradation monitoring tests.\u0000 Lab results reveal a threshold that must be exceeded in the synthesis of catalyst-free CFPCDs to achieve sufficient diamond intergrowth and structural integrity to surpass the current state-of-the-art DL PDCs. CFPCD grade A wore equivalently to a commercially available NL cutter and exhibited a toughness comparable to that of commercially available DL PDC material. Grade B, synthesized at a significantly higher pressure than grade A, cut 5.7 times the distance of a commercial NL PDC for an equivalent wearscar volume, and exhibited a 160 % reduction in wear volume comparing volume of diamond worn to volume of rock cut (or G ratios) to DL PDC after cutting the equivalent of roughly 50 miles of rock. The wearscar surface of Grade B also exhibited excellent integrity with no cracking or chipping damage compared to Grade A and commercial PDC grades. This is the first docume","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130075848","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
There are currently 4.62 billion users of social media worldwide1. This means that more than half of the population of the world uses social media (58.4%)2. The Oil and Gas sector cannot escape this reality, which is so valuable for communications and positioning strategies. One of the top-valued goals of modern organizations in all sectors is to have a positive presence on social media. For the oil and gas sector, this is particularly needed, as energy transition concepts are not necessarily well understood nor ingrained in society at large, making it difficult to revert any negative public opinion matrix about the sector. The COVID-19 pandemic forced many traditional organizations in the oil and gas sector to embrace social media, increasing their active presence on the main professional online platforms, gaining more engagement with their own employees and society like never before. This paper compares the social media presence of prominent organizations related to oil and gas in 2022, analyzing trends and highlighting opportunities and challenges. A comparison of key elements considered diagnostic in improving the recognition and reputation of oil and gas organizations are addressed in more detail, in particular sustainability and DE&I (gender representation, generally addressed as Diversty, Equity and Inclusion). Conclusions are related to cultural frameworks, selected language for postings, geo-political affinities, and the profile of the companies analyzed. Framing the current trends analyzed resulted in the identification of organizations that are more successful in the utilization of these key channels that are important to general audiences and especially to younger generations. Some unexpected findings shaped our conclusions that strategies needed for step-changes in political or cultural settings benefit greatly from the use of social media and have proven to be effective in furthering women's empowerment and for the uptake of sustainability at the corporate level.
{"title":"Social Media and the Oil & Gas Sector: Challenges and Opportunities","authors":"M. Capello, Denise Cox, Linda Battalora Battalora","doi":"10.2118/210172-ms","DOIUrl":"https://doi.org/10.2118/210172-ms","url":null,"abstract":"\u0000 There are currently 4.62 billion users of social media worldwide1. This means that more than half of the population of the world uses social media (58.4%)2. The Oil and Gas sector cannot escape this reality, which is so valuable for communications and positioning strategies. One of the top-valued goals of modern organizations in all sectors is to have a positive presence on social media. For the oil and gas sector, this is particularly needed, as energy transition concepts are not necessarily well understood nor ingrained in society at large, making it difficult to revert any negative public opinion matrix about the sector.\u0000 The COVID-19 pandemic forced many traditional organizations in the oil and gas sector to embrace social media, increasing their active presence on the main professional online platforms, gaining more engagement with their own employees and society like never before. This paper compares the social media presence of prominent organizations related to oil and gas in 2022, analyzing trends and highlighting opportunities and challenges.\u0000 A comparison of key elements considered diagnostic in improving the recognition and reputation of oil and gas organizations are addressed in more detail, in particular sustainability and DE&I (gender representation, generally addressed as Diversty, Equity and Inclusion).\u0000 Conclusions are related to cultural frameworks, selected language for postings, geo-political affinities, and the profile of the companies analyzed. Framing the current trends analyzed resulted in the identification of organizations that are more successful in the utilization of these key channels that are important to general audiences and especially to younger generations.\u0000 Some unexpected findings shaped our conclusions that strategies needed for step-changes in political or cultural settings benefit greatly from the use of social media and have proven to be effective in furthering women's empowerment and for the uptake of sustainability at the corporate level.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122495399","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Yuewei Pan, Jianhua Qin, Jing Zhang, Jianlin Shang, Wei Ma
Many pilot researches consider production gains or losses in parent/child wells in short-term thereby determining the optimal completion parameters (eg. well spacing, stage spacing). Long-term recovery varies from negative-to-positive during the post-frac-hit evaluation based on the magnitude of the pressure sink and the distance of parent/child wells. However, quantitatively analyzing frac-hits impact remains unsolved. This paper presents a novel workflow combining RTA diagnostic plots and the prediction of dynamic drainage pore volume (DDPV) to analyze the frequent well/well fracture-driven interaction (FDI) (commonly referred to as frac-hits) in the Lucaogou shale formation, Junggar Basin. According to the published knowledge, different strategies have been employed in Lucaogou formation to minimize the negative effect and to avoid the parent/child wells (e.g cube-development). Thus, optimizing stage, cluster and well spacing in well-pad zipper-frac development is in necessity. This paper first reviews the frac-hit mechanisms in both parent/child wells and well-pad zipper-frac development. We then characterize, quantify and rank the historical frac-hit events in Lucaogou formation based on the documented data. With the prediction of DDPV using numerical integration/differentiation assisted by diagnostic plots and specialized plots in RTA (eg. flowing material balance plot, square-root-of-time diagnostic plot), the pressure sink front can be acquired. The accuracy of DDPV forecast is validated using a synthetic case study. We further apply it to three field case studies to demonstrate the versatility and applicability of the proposed workflow. The successful applications suggest that the proposed workflow is an alternative to making field-development decisions, minimizing the negative impacts of frac-hits and thus freeing the cashflows. The outcomes are mainly but not limited to: 1) the common early departures from linear flow regime are in good alignment with the DDPV forecasts in both parent/child and well-pad development scenarios; 2) A competition of the per-well DDPV might be triggered during frac-hits in parent/child well and 3) long-term recovery in well-pad development with a tighter well-spacing might be boosted with a smaller per-well DDPV and DOI.
{"title":"Production Data Analysis of Shale Oil Reservoir Using the Dynamic Drainage Pore Volume Concept: Lessons-Learned from Well-To-Well Fracture Driven Interaction in Lucaogou Shale Formation","authors":"Yuewei Pan, Jianhua Qin, Jing Zhang, Jianlin Shang, Wei Ma","doi":"10.2118/210148-ms","DOIUrl":"https://doi.org/10.2118/210148-ms","url":null,"abstract":"\u0000 Many pilot researches consider production gains or losses in parent/child wells in short-term thereby determining the optimal completion parameters (eg. well spacing, stage spacing). Long-term recovery varies from negative-to-positive during the post-frac-hit evaluation based on the magnitude of the pressure sink and the distance of parent/child wells. However, quantitatively analyzing frac-hits impact remains unsolved. This paper presents a novel workflow combining RTA diagnostic plots and the prediction of dynamic drainage pore volume (DDPV) to analyze the frequent well/well fracture-driven interaction (FDI) (commonly referred to as frac-hits) in the Lucaogou shale formation, Junggar Basin.\u0000 According to the published knowledge, different strategies have been employed in Lucaogou formation to minimize the negative effect and to avoid the parent/child wells (e.g cube-development). Thus, optimizing stage, cluster and well spacing in well-pad zipper-frac development is in necessity. This paper first reviews the frac-hit mechanisms in both parent/child wells and well-pad zipper-frac development. We then characterize, quantify and rank the historical frac-hit events in Lucaogou formation based on the documented data. With the prediction of DDPV using numerical integration/differentiation assisted by diagnostic plots and specialized plots in RTA (eg. flowing material balance plot, square-root-of-time diagnostic plot), the pressure sink front can be acquired. The accuracy of DDPV forecast is validated using a synthetic case study. We further apply it to three field case studies to demonstrate the versatility and applicability of the proposed workflow.\u0000 The successful applications suggest that the proposed workflow is an alternative to making field-development decisions, minimizing the negative impacts of frac-hits and thus freeing the cashflows. The outcomes are mainly but not limited to: 1) the common early departures from linear flow regime are in good alignment with the DDPV forecasts in both parent/child and well-pad development scenarios; 2) A competition of the per-well DDPV might be triggered during frac-hits in parent/child well and 3) long-term recovery in well-pad development with a tighter well-spacing might be boosted with a smaller per-well DDPV and DOI.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126508514","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Wenhan Yue, Jiaxiang Ren, Jianpeng Yue, Pengyu Cheng, Timothy R. Dunne, Lei-feng Zhao, Matthew Patsy, D. Nettles, Yu Liu, Hua Liu
Dissolvable tools have been used more in unconventional oil and gas operations in recent years. Currently, more and more wells in Southwest of China quires high temperature (HT) dissolvable plug. The HT dissolvable plug needs to hold pressure in water at 150°C for 24 hours. On the other hand, the dissolvable plug needs to be dissolved in 1% KCl at 95°C in less than 15 days. These requirements put big challenges on dissolvable materials. Several HT dissolvable rubbers were developed to meet the requirements. The ambient and high temperature tensile testing were performed on the dissolvable rubbers. The dissolution testing of the dissolvable rubber was performed in brine at 140°C for 1 day and then at 95°C. Several dissolvable metals were developed and the slow strain rate testing (SSRT), Scanning electron Microscope (SEM)/Energy Dispersive Spectroscopy (EDS) testing were performed on these dissolvable metals. A special coating was developed to reduce the stress corrosion cracking of the dissolvable metals. Two HT dissolvable plugs were developed based on the dissolvable materials. The pressure holding testing and dissolution testing were performed on the two dissolvable plugs. It was found that the tensile strength of the HT dissolvable rubber at 150°C was higher than 1200 psi and elongation was higher than 700%, which was higher than that of most of the commercial HT dissolvable rubbers. The dissolvable rubber coupon disintegrated to tiny pieces at 95°C in 4 days. One dissolvable metal displayed better stress corrosion cracking resistance than the other dissolvable metals. The dissolvable metal promotes discontinuous grain boundaries and secondary phases within the grain boundary to prevent crack growth and propagation at the expense of strength. The dissolvable metal was used for lower slip of the dissolvable plug. The special coating on the dissolvable metal significantly reduced the dissolution rate of the dissolvable metal at high temperature. The two dissolvable plugs passed the pressure testing a of 10 ksi at 150°C in water for 24 hours. The dissolvable plug was dissolved in 1%KCl at 95°C in 14 days. The weight loss of the plug was more than 95%, All the remining residues of the dissolvable plug was less than 2 cm. The pressure holding and dissolution testing results of the dissolvable plug successfully meet the field testing requirements. This is the first time in the industry based on our knowledge a HT dissolvable plug passed 150°C, 10 ksi 24 hours pressure holding test in water and then dissolved in brine at 95°C in less than 15 days. The HT dissolvable rubber was specially designed to possess both high mechanical properties at 150°C and dissolution properties at 95°C. The dissolvable metal for lower slip was formulated to prevent crack growth.
{"title":"High Temperature Dissolvable Materials Development for High Temperature Dissolvable Plug Applications","authors":"Wenhan Yue, Jiaxiang Ren, Jianpeng Yue, Pengyu Cheng, Timothy R. Dunne, Lei-feng Zhao, Matthew Patsy, D. Nettles, Yu Liu, Hua Liu","doi":"10.2118/210238-ms","DOIUrl":"https://doi.org/10.2118/210238-ms","url":null,"abstract":"\u0000 Dissolvable tools have been used more in unconventional oil and gas operations in recent years. Currently, more and more wells in Southwest of China quires high temperature (HT) dissolvable plug. The HT dissolvable plug needs to hold pressure in water at 150°C for 24 hours. On the other hand, the dissolvable plug needs to be dissolved in 1% KCl at 95°C in less than 15 days. These requirements put big challenges on dissolvable materials.\u0000 Several HT dissolvable rubbers were developed to meet the requirements. The ambient and high temperature tensile testing were performed on the dissolvable rubbers. The dissolution testing of the dissolvable rubber was performed in brine at 140°C for 1 day and then at 95°C. Several dissolvable metals were developed and the slow strain rate testing (SSRT), Scanning electron Microscope (SEM)/Energy Dispersive Spectroscopy (EDS) testing were performed on these dissolvable metals. A special coating was developed to reduce the stress corrosion cracking of the dissolvable metals. Two HT dissolvable plugs were developed based on the dissolvable materials. The pressure holding testing and dissolution testing were performed on the two dissolvable plugs.\u0000 It was found that the tensile strength of the HT dissolvable rubber at 150°C was higher than 1200 psi and elongation was higher than 700%, which was higher than that of most of the commercial HT dissolvable rubbers. The dissolvable rubber coupon disintegrated to tiny pieces at 95°C in 4 days. One dissolvable metal displayed better stress corrosion cracking resistance than the other dissolvable metals. The dissolvable metal promotes discontinuous grain boundaries and secondary phases within the grain boundary to prevent crack growth and propagation at the expense of strength. The dissolvable metal was used for lower slip of the dissolvable plug. The special coating on the dissolvable metal significantly reduced the dissolution rate of the dissolvable metal at high temperature. The two dissolvable plugs passed the pressure testing a of 10 ksi at 150°C in water for 24 hours. The dissolvable plug was dissolved in 1%KCl at 95°C in 14 days. The weight loss of the plug was more than 95%, All the remining residues of the dissolvable plug was less than 2 cm. The pressure holding and dissolution testing results of the dissolvable plug successfully meet the field testing requirements.\u0000 This is the first time in the industry based on our knowledge a HT dissolvable plug passed 150°C, 10 ksi 24 hours pressure holding test in water and then dissolved in brine at 95°C in less than 15 days. The HT dissolvable rubber was specially designed to possess both high mechanical properties at 150°C and dissolution properties at 95°C. The dissolvable metal for lower slip was formulated to prevent crack growth.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"73 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122318299","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In September 2021, the Alberta Energy Regulator (AER) through a new pressure and deliverability testing directive issued new guidance for minifrac tests, also known as diagnostic fracture injection tests, to align with the current practice for conducting these tests. This paper statistically summarizes results from 83 of these DFITs, submitted by many operators from the Canadian Duvernay shale play. The main parameters analyzed were closure, reservoir pressure and permeability. This newly updated directive sets out requirements for pressure and deliverability tests. In the development of tight or unconventional reservoirs, industry moved towards horizontal wells with multistage fracture treatments using a minifrac (also referred to as DFIT or diagnostic fracture injection test), which became the more common well test in determining closure, initial reservoir pressure and permeability. In this paper, a comparison of holistic vs compliance methods descriptions for closure pressure are provided. Complete governing equations for after closure analysis methods are described in detail to permit readers to replicate all results on reservoir pressure and permeability. For closure pressure, the compliance model is compared to the holistic model that is published or commercially available. Comparisons are also provided for After Closure Analysis (ACA) models including the Soliman and Nolte methods as far as reservoir pressure and permeability are concerned. 83 field case studies are presented for horizontal wells in an unconventional shale play. The most significant findings are 1) a compliance closure pressure signature is not apparent in the analyzed DFITs, 2) closure pressure estimates, and outcomes are similar for the compliance and holistic methods 3) reservoir pressure determination differentiation using either linear or radial flow 4) PVT impact on interpretation and 5) order of magnitude difference for permeability determination on After Closure Analysis methods. The findings have direct practical implications for operators in the Canadian Duvernay shale play and analogous shale plays in USA and elsewhere. Accurate permeability estimates are needed for calculating effective fracture length and for optimizing well spacing and fracture design. Accurate closure pressure is fundamental to hydraulic fracture design and other geomechanics applications. Accurate initial reservoir pressure is important because it could be used for input for Rate Transient Analysis (RTA) for resources / reserves assessments in similar unconventional plays. The novelty of the comparative analysis is in the ability to show in unconventional shale plays how closure pressure methods compared, and the implications of using different after closure analysis methods which could be of significant benefit to a practicing engineer or well testing interpreter
{"title":"Best Practices in DFIT Interpretation - Comparative Analysis of 83 DFITs in the Canadian Duvernay Shale Play","authors":"C. Virues, Alexandra Robertson, Emile AbouKhalil","doi":"10.2118/210266-ms","DOIUrl":"https://doi.org/10.2118/210266-ms","url":null,"abstract":"\u0000 In September 2021, the Alberta Energy Regulator (AER) through a new pressure and deliverability testing directive issued new guidance for minifrac tests, also known as diagnostic fracture injection tests, to align with the current practice for conducting these tests. This paper statistically summarizes results from 83 of these DFITs, submitted by many operators from the Canadian Duvernay shale play. The main parameters analyzed were closure, reservoir pressure and permeability.\u0000 This newly updated directive sets out requirements for pressure and deliverability tests. In the development of tight or unconventional reservoirs, industry moved towards horizontal wells with multistage fracture treatments using a minifrac (also referred to as DFIT or diagnostic fracture injection test), which became the more common well test in determining closure, initial reservoir pressure and permeability. In this paper, a comparison of holistic vs compliance methods descriptions for closure pressure are provided. Complete governing equations for after closure analysis methods are described in detail to permit readers to replicate all results on reservoir pressure and permeability.\u0000 For closure pressure, the compliance model is compared to the holistic model that is published or commercially available. Comparisons are also provided for After Closure Analysis (ACA) models including the Soliman and Nolte methods as far as reservoir pressure and permeability are concerned. 83 field case studies are presented for horizontal wells in an unconventional shale play. The most significant findings are 1) a compliance closure pressure signature is not apparent in the analyzed DFITs, 2) closure pressure estimates, and outcomes are similar for the compliance and holistic methods 3) reservoir pressure determination differentiation using either linear or radial flow 4) PVT impact on interpretation and 5) order of magnitude difference for permeability determination on After Closure Analysis methods. The findings have direct practical implications for operators in the Canadian Duvernay shale play and analogous shale plays in USA and elsewhere. Accurate permeability estimates are needed for calculating effective fracture length and for optimizing well spacing and fracture design. Accurate closure pressure is fundamental to hydraulic fracture design and other geomechanics applications. Accurate initial reservoir pressure is important because it could be used for input for Rate Transient Analysis (RTA) for resources / reserves assessments in similar unconventional plays.\u0000 The novelty of the comparative analysis is in the ability to show in unconventional shale plays how closure pressure methods compared, and the implications of using different after closure analysis methods which could be of significant benefit to a practicing engineer or well testing interpreter","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131535042","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Albania has an active but challenging drilling activity that demands the most innovative technology. Although new recent drilling activity, has discovered light crude oil, the predominant crude oil quality involves medium-heavy oil reservoirs mainly contained in the largest onshore European oilfield, Patos-Marinza. Even though it has high potential, Albania’s main reservoirs are practically under-developed. In the past decade, the Albanian institutions have increasingly encouraged and supported expanding drilling activity in an effort to stimulate investments in reservoir development/production and management. However, petroleum economics and appropriate management systems need to be further improved to assist in reserve ‘asset’ management. This requires, specifically, employing a collective reserves management system, Petroleum Resources Management System (PRMS), which utilizes a framework and guidelines for resource competencies to evoke necessary asset management in reserves and resources. In this paper, a basic outlook is undertaken to evaluate Albania’s resources and oil/gas reserves in a preliminary assessment to classify the reserves under the PRMS guidelines. The main idea will show how a small country with great potential, can exploit its vast resources, and ultimately capitalize on a structured systematic approach by essentially arranging a management system that is customizable and suitable as per its situation to ultimately leverage financial gains. Additionally, an analogous resources management system that is used for characterizing and identifying possible storage areas for CO2 (carbon sequestration) will also be briefly introduced that is based on the CO2 Storage Resource Management System (CO2-SRMS). Which, herein, will spotlight possible suitable areas of carbon storage in Albania. These types of management systems are crucial in decision making, offering considerably ‘better judgments’ in managing and developing resources by ranking the most suitable investment opportunities.
{"title":"Principles for Managing Reserves and Resources in Albania via Petroleum Resources Management System","authors":"Bez Buranaj Hoxha","doi":"10.2118/210165-ms","DOIUrl":"https://doi.org/10.2118/210165-ms","url":null,"abstract":"\u0000 Albania has an active but challenging drilling activity that demands the most innovative technology. Although new recent drilling activity, has discovered light crude oil, the predominant crude oil quality involves medium-heavy oil reservoirs mainly contained in the largest onshore European oilfield, Patos-Marinza. Even though it has high potential, Albania’s main reservoirs are practically under-developed. In the past decade, the Albanian institutions have increasingly encouraged and supported expanding drilling activity in an effort to stimulate investments in reservoir development/production and management. However, petroleum economics and appropriate management systems need to be further improved to assist in reserve ‘asset’ management. This requires, specifically, employing a collective reserves management system, Petroleum Resources Management System (PRMS), which utilizes a framework and guidelines for resource competencies to evoke necessary asset management in reserves and resources.\u0000 In this paper, a basic outlook is undertaken to evaluate Albania’s resources and oil/gas reserves in a preliminary assessment to classify the reserves under the PRMS guidelines. The main idea will show how a small country with great potential, can exploit its vast resources, and ultimately capitalize on a structured systematic approach by essentially arranging a management system that is customizable and suitable as per its situation to ultimately leverage financial gains.\u0000 Additionally, an analogous resources management system that is used for characterizing and identifying possible storage areas for CO2 (carbon sequestration) will also be briefly introduced that is based on the CO2 Storage Resource Management System (CO2-SRMS). Which, herein, will spotlight possible suitable areas of carbon storage in Albania.\u0000 These types of management systems are crucial in decision making, offering considerably ‘better judgments’ in managing and developing resources by ranking the most suitable investment opportunities.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"178 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134158333","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A new and robust tracer technology is introduced based on encapsulated Nano-sized synthetic DNA. This cutting-edge technology enables bonding of synthetic DNA strands with unique sequences to a magnetic core particle and encapsulating them with silica making it possible to have unlimited number of identifiable tracers, each with a unique signature. Each manufactured batch of DNA tracer is then coated with a special chemical to make the batch water-wet or oil-wet. The presented novel technology of encapsulated Nano-sized DNA tracers is shown to be superior to the currently used water chemical tracers, fluorobenzoic acid or FBA, in many ways both in the applications of EOR and flowback analyses in hydraulic fracturing. Unlike the chemical tracers, the DNA tracers don't partition, don't chemically react with the formation minerology, don't disintegrate with time, are stable at high reservoir temperatures and don't lag flood front velocity if used in secondary recovery projects such as waterflooding. In addition, unlike the available limited number of chemical tracers, there are unlimited number of identifiable DNA tracers. In waterflooding, the DNA tracers are used to characterize fluid flow accurately and precisely in a reservoir and to identify heterogeneity of the reservoir. The technology can also be used to evaluate flowback analyses in hydraulic fracturing to fully understand fracture behavior, pipeline leakage identification, groundwater movement, contamination tracking in water streams, etc.
{"title":"Laboratory Investigation of Chemical Tracers vs. DNA Tracers","authors":"M. Asadi, Tyler Blair, Sarah Comstock","doi":"10.2118/209954-ms","DOIUrl":"https://doi.org/10.2118/209954-ms","url":null,"abstract":"\u0000 A new and robust tracer technology is introduced based on encapsulated Nano-sized synthetic DNA. This cutting-edge technology enables bonding of synthetic DNA strands with unique sequences to a magnetic core particle and encapsulating them with silica making it possible to have unlimited number of identifiable tracers, each with a unique signature. Each manufactured batch of DNA tracer is then coated with a special chemical to make the batch water-wet or oil-wet. The presented novel technology of encapsulated Nano-sized DNA tracers is shown to be superior to the currently used water chemical tracers, fluorobenzoic acid or FBA, in many ways both in the applications of EOR and flowback analyses in hydraulic fracturing. Unlike the chemical tracers, the DNA tracers don't partition, don't chemically react with the formation minerology, don't disintegrate with time, are stable at high reservoir temperatures and don't lag flood front velocity if used in secondary recovery projects such as waterflooding. In addition, unlike the available limited number of chemical tracers, there are unlimited number of identifiable DNA tracers. In waterflooding, the DNA tracers are used to characterize fluid flow accurately and precisely in a reservoir and to identify heterogeneity of the reservoir. The technology can also be used to evaluate flowback analyses in hydraulic fracturing to fully understand fracture behavior, pipeline leakage identification, groundwater movement, contamination tracking in water streams, etc.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"111 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123970108","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Kortam, Ihab Sobhi, Mahmoud Khalil, Omar Yahia, N. Spurr
A well, with very low bottomhole pressure, required frequent workover operations due to pump failures from sand production. A gravel pack was designed to minimize the production sand issues. However, to sustain low pore pressure (less than 0.1 psi/ft) without affecting well productivity, lower drawdown was needed during an acceptable sand control completion. This presented a challenge due to massive completion brine losses and increased risk of formation damage. These challenges could create impairment in well productivity. Usually, a rig utilizing coiled tubing is used to handle the flowback and unload the well. To increase the amounts of flowback fluid, and minimize formation damage, the completion of this well used a neutral wet proppant. The proppant, which had surfaces that are neither oil nor water wet, was used in this gravel pack to improve the flowback fluids recovery. The expected benefits of this proppant were to (1) eliminate capillary pressure within the proppant pack and (2) alter the interaction between aqueous/organic (hydrocarbons) and the proppant surfaces. This would be accomplished by decreasing the intra-molecular interactions between the fluids and the proppant surfaces thus resulting in improved flow compared to native surfaces. Lightweight ceramic (LWC), neutral-wettability proppant was used to improve clean-up and enhance fluid flowback recovery. Extensive laboratory testing on the proppant was performed ahead of the job, including properties and compatibility with stimulation fluid. This proppant had both hydro- and oleophobic properties. The hydrophobic properties improve the flow of the aqueous fluids, while the oleophobic properties improve the flow of the hydrocarbon phase. The proppant was pumped similarly to any other conventional proppant and no changes in the procedures were needed. After completion of the job, the well was shut-in and the flowback un-loading was performed a week later. This completion relied on using ESP to perform the cleanup and producing the well concurrently to reduce the operation time and cost spent during well unloading. After completion, 100% of all pumped brine was recovered leading to an enhanced production rate with no impairment or coiled tubing lifting post treatment required. The cleanup was carried out after one week from the treatment date. The well cleanup, in comparison with wells that used conventional proppant, was much faster and saved $50,000. The calculated productivity index is 3.2 compared with 2.8 bpd/psi before the treatment representing 15 % gain. No sand production was observed during production performance nor seen in the wellbore during pump replacement after two years of continuous production period. The average run life prior to this treatment was 3 months, thus impacting not only the well productivity but also the run well life.
{"title":"Neutral-We Proppant Improves Post Treatment Cleanup and Enhances Productivity","authors":"M. Kortam, Ihab Sobhi, Mahmoud Khalil, Omar Yahia, N. Spurr","doi":"10.2118/210097-ms","DOIUrl":"https://doi.org/10.2118/210097-ms","url":null,"abstract":"\u0000 A well, with very low bottomhole pressure, required frequent workover operations due to pump failures from sand production. A gravel pack was designed to minimize the production sand issues. However, to sustain low pore pressure (less than 0.1 psi/ft) without affecting well productivity, lower drawdown was needed during an acceptable sand control completion. This presented a challenge due to massive completion brine losses and increased risk of formation damage. These challenges could create impairment in well productivity. Usually, a rig utilizing coiled tubing is used to handle the flowback and unload the well.\u0000 To increase the amounts of flowback fluid, and minimize formation damage, the completion of this well used a neutral wet proppant. The proppant, which had surfaces that are neither oil nor water wet, was used in this gravel pack to improve the flowback fluids recovery. The expected benefits of this proppant were to (1) eliminate capillary pressure within the proppant pack and (2) alter the interaction between aqueous/organic (hydrocarbons) and the proppant surfaces. This would be accomplished by decreasing the intra-molecular interactions between the fluids and the proppant surfaces thus resulting in improved flow compared to native surfaces.\u0000 Lightweight ceramic (LWC), neutral-wettability proppant was used to improve clean-up and enhance fluid flowback recovery. Extensive laboratory testing on the proppant was performed ahead of the job, including properties and compatibility with stimulation fluid. This proppant had both hydro- and oleophobic properties. The hydrophobic properties improve the flow of the aqueous fluids, while the oleophobic properties improve the flow of the hydrocarbon phase. The proppant was pumped similarly to any other conventional proppant and no changes in the procedures were needed. After completion of the job, the well was shut-in and the flowback un-loading was performed a week later. This completion relied on using ESP to perform the cleanup and producing the well concurrently to reduce the operation time and cost spent during well unloading.\u0000 After completion, 100% of all pumped brine was recovered leading to an enhanced production rate with no impairment or coiled tubing lifting post treatment required. The cleanup was carried out after one week from the treatment date. The well cleanup, in comparison with wells that used conventional proppant, was much faster and saved $50,000. The calculated productivity index is 3.2 compared with 2.8 bpd/psi before the treatment representing 15 % gain. No sand production was observed during production performance nor seen in the wellbore during pump replacement after two years of continuous production period. The average run life prior to this treatment was 3 months, thus impacting not only the well productivity but also the run well life.","PeriodicalId":113697,"journal":{"name":"Day 2 Tue, October 04, 2022","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124365150","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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