Day 3 Wed, February 23, 2022最新文献

{"title":"Competitive Evaluation of Malaysia Enhanced Profitability Terms with Southeast Asia Fiscal Terms","authors":"Choong Heng Lim, T. Dharmadji, Azrin Kassim, Muhammad Usman Ul Haq Sethi, Muhammad Kamran Qureshi","doi":"10.2523/iptc-22162-ms","DOIUrl":"https://doi.org/10.2523/iptc-22162-ms","url":null,"abstract":"\u0000 Malaysia has introduced a shallow-water enhanced profitability term (EPT) production sharing contract (PSC) in the year 2021 to reward a PSC contractor with equitable returns reflecting the business risk and the opportunity to accelerate development and monetization. This study evaluates the attractiveness of the EPT against several fiscal terms adopted in southeast Asia, including Indonesia, Vietnam, Thailand, and Myanmar.\u0000 This paper established an offshore shallow-water field development analogue project with a total production volume of 68 MMbbl, capital expenditure (Capex) of USD 530 million, predevelopment operating expenditure (Opex) of USD 36 million, variable Opex of USD 12.5/bbl, floating production storage and offloading (FPSO) rental of USD 61 million/year, and abandonment capital of USD 101 million. High, base, and low scenarios are considered for oil price per barrel as USD 70, 60, and 50, respectively, and production volume scenarios as 78, 68, and 58 MMbbl, respectively. These values with certain fiscal assumptions are input into a fiscal model engine for economic indicators [net present value (NPV), rate of return (ROR), and payback], revenue take, after-tax cashflow, and variables sensitivity calculations to evaluate base, optimistic, and pessimistic cases.\u0000 In the base case, the attractiveness order of countries based on a higher-positive NPV at 10% and ROR are Malaysia EPT (NPV at 10% = USD 198 million, ROR = 30.4%), Indonesia PSC (2017) (NPV at 10% = USD 149 million, ROR = 28.3%), and Thailand Royalty and Tax (R/T; 1991) (NPV at 10% = USD 32 million, ROR = 14.5%).\u0000 In the optimistic case, the NPVs at 10% are improved, ranging from Thailand (+271%), Myanmar (+247%), Malaysia (+151%), and Indonesia and Vietnam (+141%) as compared to the base case. In the pessimistic case, all the fiscal terms are unfeasible for ROR at 10%. Myanmar PSC (1993) yields above 10% ROR only when the production is at the base or high scenario with oil price at USD 70/bbl. Vietnam PSC (2013) is unfeasible for positive NPV at 10% even with high oil price under various taxes, including the windfall profit tax. Indonesia has a better NPV at 10% at a low oil price because of the progressive split that subsidizes the operator. Oil price and production volume are the top two sensitive variables except for Vietnam, where capital is the highest. The contractor take is higher in Malaysia, followed by Indonesia, Thailand, Myanmar, and Vietnam at base and high oil price. When the oil price is low, Indonesia generated a higher contractor take than Malaysia. Malaysia EPT is the only fiscal regime that can generate a contractor take that is higher than government take and stagnant around 55% against the 40% in Indonesia. In conclusion, Malaysia EPT provides a better investment return when the oil price is USD 60/bbl and above, while Indonesia gross split is more profitable when the oil price is low.\u0000 This study provides insights on the potential investment returns ","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78515767","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}

{"title":"Case Study: Single Well Design Targeting Three Water Bearing Formations","authors":"Hamad Al-Qattan, Emad Al-Jassam, Magdy Mansour, Mahmoud Morcey","doi":"10.2523/iptc-21971-ms","DOIUrl":"https://doi.org/10.2523/iptc-21971-ms","url":null,"abstract":"\u0000 Designing an onshore pilot well to be drilled and functioning as water disposal well targeting one of three potential formations to test and evaluate their injectivity. Based on evaluation results, an alternative new and deeper formation will be selected to dispose the unwanted associated produced water, instead of the current shallow formation that is considered as a natural aquifer by authorities.\u0000 The well is designed to reach the first target in a deviated angle after which evaluation of the barefoot injectivity testing will begin. The decision whether to continue drilling to a secondary target or complete the well depends heavily on the injectivity testing results.\u0000 The deviated angle of drilling will be dropped to reach a vertical position for the secondary target upon which the last liner will be run and perforated, then the formation testing will be conducted. In case of encounterg failure in the second injectivity testing, drilling to the deepest target will continue and final barefoot testing will be performed.\u0000 A final optimal design for the pilot disposal well is intended to meet the reservoir and geological team with minimal drilling risks. The distance between this well and the other deep offset wells was the main challenge where the planned total depth was never reached in the disposal location. Also, the design was tailored to accommodate the drilling sections with the separation and long intervals between the targets. Furthermore, the uncertainty of the deepest formation fluid in addition to the uncertainties of formations pressure and formations fracture pressure were a big dispute while preparing the drilling fluids programs particularly across the target in which a water based mud was used as drilling fluid not to damage the formations nor to jeopardize the results of the injectivity tests.\u0000 The pilot disposal well is drilled successfully penetrating two targets without the need to drill to the third formation. Hence, the new formation that will be used to dispose of the produced but unwanted water is defined after the reservoir team have evaluated the two injectivity tests. The results of the injectivity evaluation also provided the required number of wells that can handle all the expected produced water, and provided the required upgrade for the surface facilities to accommodate the injection pressure.\u0000 This unique challenging well design, combining slanted and vertical trajectories, can be utilized whenever the budget is limited to one well, while you have multiple different targets to explore.\u0000 Moreover, a specialized environmental impact study, conducted by independent contractor, confirms that there was no harm from the injected water to the groundwater.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84459232","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}

{"title":"Optimization of NMR Permeability Transform and Application to a Source Rock Reservoir","authors":"Jin-Hong Chen, Stacey M Althaus, M. Boudjatit","doi":"10.2523/iptc-22195-ea","DOIUrl":"https://doi.org/10.2523/iptc-22195-ea","url":null,"abstract":"\u0000 Permeability is a fundamentally important property of reservoir rocks that governs the flow of the reservoir fluids and production rates. Many methods have been developed to estimate permeability, including well established and documented laboratory measurements on whole core and plugs, analysis of formation test data, and analysis of production. Obtaining permeability from nuclear magnetic resonance (NMR) T1 or T2 has proven to be a cost effective method that can provide continuous permeability along a wellbore. This method uses a transform function on NMR well log data to calculate permeability. An accurate NMR permeability transform requires calibration to fit local data of a specific field based on measured data from representative cores from the field. The general form of the permeability transform developed for conventional sandstone and carbonate reservoirs does not work well for extremely tight reservoirs such as source rocks. Here we show a generic optimization method to find the optimal permeability transform for any tight reservoirs using NMR log data and laboratory measured permeability data from samples at selected depth of the logged well. This optimization method is applied to a source rock well and a permeability transform was obtained. The transform is a function of the movable fluid in the rock and logarithm mean of the NMR relaxation time. The permeability calculated from the transform is comparable to measured permeability from core samples.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85359310","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}

{"title":"Opportunities and Challenges of Steam Generation Using Renewable Energy for Enhanced Oil Recovery Applications: Concepts Overview","authors":"Idris Al Siyabi, Aiman Al Shukaili, M. Al Ajmi, R. Mujaini, Moosa Al Amri, A. Al Ghufaili, Marwa Al Harrasi, Bader Al Ma'Mari","doi":"10.2523/iptc-22370-ms","DOIUrl":"https://doi.org/10.2523/iptc-22370-ms","url":null,"abstract":"\u0000 Steam generation for the Enhanced Oil Recovery (EOR) using steam injection is considered as one of critical production process in heavy oil industry. It requires a massive amount of thermal energy to generate one ton of steam. The conventional steam generation processes use natural gas as fuel where high amount of emissions is released to ambient. The recent cost reductions of the energy generated by the renewable energy attracts organizations to adopt it. Different technologies such as PV, CSP, electric heaters and thermal energy storage can be integrated to generate steam using the renewable resources of solar and wind. The study explores the different potential of adopting such technologies and the challenges associated with them where the mismatch between the supply and the demand of energy is the main challenge and could be mitigated through storage solutions and the consideration of hybrid system with the conventional steam generation.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"53 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85732064","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}

{"title":"Higher-Order Derivatives of Production Rate and Convolutional Neural Network for Production Forecasts","authors":"Syed Tabish Haider, T. Patzek","doi":"10.2523/iptc-22486-ms","DOIUrl":"https://doi.org/10.2523/iptc-22486-ms","url":null,"abstract":"\u0000 In recent years, many machine-learning models have been developed to predict future production of oil in gas in \"shales\". Long-short term memory (LSTM), the most widely used model, relies on the long-term production history for a reasonably accurate production forecast. All analytical and machine learning models, including LSTM, fail miserably in the absence of long production history. Our goal is to present a novel method of production forecasting using only 24 months of production data. The first and secondorder derivatives of the distance traveled give speed and acceleration to describe the trajectory and dynamics of a moving vehicle. Similarly, higher-order derivatives of hydrocarbon/water production rate vs. time uncover hidden patterns and fluctuations in a well that act as differential markers of its future recovery factor (RF). In this paper, we couple production data and their higher-order derivatives with other known parameters for a well, i.e., well length and initial production. The time-series data are passed into a Convolutional Neural Network (CNN) with two hidden layers of 16 nodes each, and one output layer. The model is trained to predict recovery factor (RF) in the 10th year of production. We analyze the first 24 months of production data for the Barnett (1500), Marcellus (800), Haynesville (800), and Eagle Ford (1000) shale wells. All wells have a minimum pressure interference time of 34 months. The production rate vs. time and its first, second, and third-order derivatives are coupled with the well length and initial production rate, and the data are normalized with their respective maxima. For the Barnett wells, the CNN model predicts recovery factors in their 10th year of production with an average accuracy of 90%. For the Marcellus, Haynesville, and Eagle Ford wells, the prediction accuracy in the 8th year of production is 89%, 92%, and 91%, respectively. Further, we divide the wells into three groups (A, B, C) depending on the range of their recovery factor (A:RF=0-0.3, B:RF=0.3-0.6, and C:RF=0.6-0.9). We show that the clusters of wells grouped by their RFs strongly correlate with the distribution of the higher-order de rivatives of production from these wells. Thus, we posit that the detailed production history and its derivatives are the most important variables that define distributions of maximum recoverable hydrocarbon from a source rock. Our novel method uses only 24 months of production data to predict future recovery factor with an outstanding average accuracy of 90%. We show that the higher-order derivatives of high-resolution production data available from the operators could be an excellent tool for well screening and predicting future production with reasonable accuracy.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"43 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80842211","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}

{"title":"Longest 9 5/8? Casing Cementing in ERD Well, A Worldwide-Record","authors":"Alejandro De la Cruz Sasso, Hussien Alzaki, Rodny Masoud Zuleta, Nawaf Saud AlShammari","doi":"10.2523/iptc-22082-ms","DOIUrl":"https://doi.org/10.2523/iptc-22082-ms","url":null,"abstract":"\u0000 The efficient placement of cement as a verified barrier above a distinct permeable zone in any oil and gas well is a constant challenge faced by the industry. Absence of isolation behind the casing represents a deficiency to the required well integrity barriers. A compromised well barrier may result in casing corrosion, leaks, and eventually sustained casing pressure which might lead the loss of the asset and/or endanger the safety or workers and/or the environment.\u0000 Ultimately, a compromised barrier implies compromised well integrity. Fluid displacement in ERD wells is different from conventional wells and the job conditions pose additional challenges. To ensure adequate cement placement in this ultra-ERD well, several challenges had to be addressed. Hence, an optimized cement placement method that focused on ECD management to prevent induced loss circulation included maintaining fluids displacement regimes, fluid density, and hydraulic friction hierarchy. Moreover, casing centralization was imperative. Limiting casing string movement once the string deployed successfully to bottom equally added to the challenge.\u0000 A system's approach was utilized to achieve the level of optimization desired. Slurry rheology and fluid loss control were adjusted. A pumping schedulethat ensured that optimum displacement efficiencies were achieved in line with the designed rheology was used. The impact of pump rates on downhole ECD regimes were equally evaluated and confirmed to be fit-for-purpose. Mud conditioning prior to the cement displacement and spacer wettability were also of paramount importance. A centralizer spacing resulting in >70% stand-off was utilized. These optimized practices represented the results of 3D modeling used to understand the fluid dynamics, and its distribution under the influence of a horizontal static pipe. This work also presented a comprehensive sensitivity analysis not only on the effects of thermal thinning on fluid rheology, but also on gravitational forces acting on the fluids in an ERD well. After execution, a combination of cement bond logs, ultrasonic measurements, and advanced interpretation techniques were used to evaluate the cement bond quality. The logs showed an improved cement bonding with minimal to no channeling, and excellent radial cement coverage.\u0000 As global hydrocarbon resources become harder to reach, ERD wells maybe required to access such subsurface targets. Adequate cementing well integrity is crucial to assuring the long-term integrity of such wells for the economic life of the assets. The practices implemented in this case history will contribute to expanding the tools and techniques available to engineers to achieving excellent barrier isolation in such wells.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87913287","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}

{"title":"Influence of Temperature Profile Modelling on the Accuracy of Hydraulic Parameters Estimation Effect of Temperature Profile Change Due to Continuous Drillstring Rotation","authors":"A. Zherelyev, J. B. Molster","doi":"10.2523/iptc-22030-ea","DOIUrl":"https://doi.org/10.2523/iptc-22030-ea","url":null,"abstract":"\u0000 ERD wells are widely used by operators in the MENA region to maximize reservoir contact, lower cost per barrel accessed, and to be able to access far away drill targets from fewer drill centers (wellhead platforms, islands, drill pads). ERD wells and associated required technological well construction approaches by nature are typically non-standard. ERD well construction require very exact and detailed engineering analysis and methodologies to be applied in order to develop suitable and accurate drilling designs that closely matches to the actual conditions. During drilling of ERD wells, a ME operator observed that the static geothermal gradient and subsequent modelling of dynamic flow temperature did not match actual downhole temperatures, hence modifications were required to the temperature profile to match the simulation of OBM drilling fluid ECD (Equivalent Circulating Density) to actual ECD measurements from the ECD pressure sub in the BHA. This temperature effect arises from the several factors, mainly in the sub-surface environment. The resulting mud temperature is significantly higher than static temperature and this has a high impact on mud rheology, resulting pressure losses and hole cleaning. Failure to model correctly can result in mud losses or loss of horizontal section because the ECD gets above formation fracture gradient, to low flowrates for effective hole cleaning due to excessive standpipe pressures, and other problems. This paper presents how hydraulics were modelled to match actual data (rheology, ECD, SPP, BHA, Flowrate, ROP, RPM etc) in one of the longest ERD wells ever drilled.\u0000 In response to the challenges faced by a ME operator to improve the quality of hydraulic modelling and drilling design, a global Oil and Gas service company and a ME operator jointly explored the approaches for simulating Effective Temperature Profile on the giant offshore oil field, calibrated and verified it along hole with application for providing accurate estimation of hydraulic parameters. The workflow starts from analysis of actual temperature readings in upper sections of the well then uses it for simulating of Effective Temperature Profile in the reservoir section. Then simulated Effective Temperature Profile is imported to the simulation tool for proper drilling design.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90309301","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}

{"title":"Extended Elastic Impedance and its Application in Prediction of Reservoir and Fluid Properties for Late Messinian Reservoir, Onshore Nile Delta Egypt","authors":"Mahmoud Eloribi, Hytham Raslan","doi":"10.2523/iptc-21923-ms","DOIUrl":"https://doi.org/10.2523/iptc-21923-ms","url":null,"abstract":"\u0000 The study area is situated within the eastern portion of the Nile Delta. As the Mediterranean Sea \"dried up\" during the Messinian extensive erosion process resulted in the formation of large canyons and valleys which cut into the underlying Qawasim and Sidi Salim Formations, but the number of such incised valleys may have been limited. The entrenched valleys became filled predominantly with sandstone as sea levels frequently rose and dropped in the late Miocene to early Pliocene. The marine influence on deposition during the late Messinian became strong toward the end of the Miocene when thick marine shale separated the sand bodies.\u0000 Late Messinian reservoir within the study area exhibits a good quality reservoir for gas and condensate accumulation. The target reservoir section consists of structural and stratigraphic elements that control the gas presence and the GWC.\u0000 Late Messinian reservoir has a lot of heterogeneity and ambiguity for the attributes and amplitude interpretation, so the DHI within the study area has pitfalls and uncertainty to determine the hydrocarbon prospects, which caused the drilling of several dry wells. For lithology and pore fluid prediction, several hypotheses and approaches had been proposed. Amplitude versus offset (AVO) modeling and analysis for the wells log and seismic angle gathers data results in non-unique output, whereas several AVO classes were found for the gas sand within the study area. The AVO analysis for gas sand of the late Messinian reservoir could be Class II and Class IIp, while the wet sand is Class I.\u0000 Following the first discovery within the study area, Extended Elastic Impedance (EEI) inversion was carried out for the Late Messinian reservoir for better identification and delineation of the reservoir boundaries and to determine the pore fluid content. During this study, several iterations have been made to determine the most appropriate chi angles to illuminate the presence of both reservoir and borehole content.\u0000 The EEI inversion results show a strong correlation between a certain chi angle and the presence of gas. Maps for the late Messinian reservoir have been produced to illuminate the gas sand presence, which matches the results of the drilled wells. The technique has been so successful, as there are unexplored EEI anomalies that have a gas signature within the fault downthrown area. These EEI anomalies had been tested with encouraging results of a gas-bearing sand reservoir, as the EEI anomaly had been predicted correctly.\u0000 This paper discusses the methodology involved, the calibration, and the selection of the appropriate chi angles for the Late Messinian Reservoir within the study area.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"64 5 Pt 1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90418431","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}

{"title":"Data Driven Intelligent Modeling to Estimate Adsorption of Methane Gas in Shales","authors":"S. Kalam, S. Abu-Khamsin, Mohammad Rasheed Khan, Asiya Abbasi, Abdul Asad, Rizwan Ahmed Khan","doi":"10.2523/iptc-22101-ms","DOIUrl":"https://doi.org/10.2523/iptc-22101-ms","url":null,"abstract":"\u0000 Artificial intelligence is a smart tool widely used in Petroleum engineering. Adaptive Neuro-Fuzzy Inference System (ANFIS) is an artificial intelligence technique that is a hybrid between Artificial Neural Networks (ANN) and fuzzy logic. In this paper, both ANN and ANFIS were applied to propose a new methodology based on intelligent algorithms to predict adsorption of methane gas in shale. Feed-Forward Neural Network and subtractive clustering were applied to correlate adsorption with several parameters. These include temperature, pressure, moisture content, and total organic content (TOC).\u0000 A real data set collected from the literature, which includes about 350 data points, was used in the development of a new empirical correlation. The set was divided into a 70:30 ratio for training and testing, respectively. The average absolute percentage error, correlation coefficient, and mean squared error were considered in the error metrics to obtain the best possible model.\u0000 The results show that methane adsorption can be efficiently correlated with the inputs using both machine learning tools. Using ANN, the correlation coefficient for both testing and training data was more than 99%. A detailed sensitivity analysis for the ANN model is also provided in this paper.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"36 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78393361","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}

{"title":"Hydraulic Fracture Conductivity Sustenance in Carbonate Formations Through Rock Strengthening by DAP Solution","authors":"Y. Samarkin, M. Aljawad, A. Amao, T. Sølling, K. Al-Ramadan, S. Abu-Khamsin, S. Patil, M. AlTammar, K. Alruwaili","doi":"10.2523/iptc-22496-ms","DOIUrl":"https://doi.org/10.2523/iptc-22496-ms","url":null,"abstract":"\u0000 Hydraulic fracturing operations involve generating conductive pathways in low permeability formations to maximize hydrocarbons production. One of the main challenges is maintaining fracture conductivity under high closure stresses, especially in soft formations. However, long–term fracture conductivity can be sustained through fracture surface hardness improvement. This research targets the strengthening of carbonate rocks via the transformation of calcite into the harder hydroxyapatite mineral.\u0000 In this study, limestone, chalk, and dolomite rock specimens were treated with 1M solution of diammonium phosphate (DAP) for 3 days at room temperature conditions. Rock samples’ hardness was measured by indentation (Brinell hardness) technique before/after the treatment to assess the strengthening effect of DAP. The changes in the mineralogy in treated samples were studied by SEM-EDS technique.\u0000 The formation of phosphate minerals was achieved in treated samples, and they were clearly seen in the SEM images. The results have shown that both limestone and chalk samples reacted strongly with DAP solution, which was expressed in terms of rich abundance in newly formed minerals inside rock specimens. The reaction between dolomite and DAP solution was observed to be weak which resulted in generation of isolated phosphate minerals. The formed minerals were identified as hydroxyapatite (5 hardness in the Mohs scale) after comparing their morphology with other phosphate minerals reported in the literature. Treatment of the rocks by DAP solution resulted in improvement of their strength. The Brinell hardness of the chalk specimen was increased by 30% after the treatment, whereas in the case of the limestone sample, a 13% increment in hardness was achieved.\u0000 The proposed carbonate rock strengthening technique can be applied in hydraulic fracturing It is intended to solve common soft formations problems (e.g., asperities failure, proppant embedment) causing acid/propped fractures’ conductivity reduction.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85530532","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}