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Water Shutoff and Conformance Improvement for Lamadian Oilfield in daqing Using a Novel Polymer System: Experimental Study, Simulation, and Pilot Tests

Water Shutoff and Conformance Improvement for Lamadian Oilfi...

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2023 Abu dhabi International Petroleum Exhibition and Conference, AdIP 2023

作者： Lu, Meng Singh, Harpreet Li, Jianshen Huang, Qiushi Ma, Chi Shan, Gaojun du, Qinglong Cai, Meng Wang, Haitao Liu, Xiangbin Qiao, Yan Chen, Huan Chen, Zhao Nie, Cong CNPC USA Corp HoustonTX United States CNPC Engineering Technology R&D Company Limited Beijing China PetroChina Daqing Oilfield Company Heilongjiang Daqing China

ISBN: (纸本)9781959025078

Primary recovery and extensive waterflooding lead to preferential pathway for the water between injectors and producers, resulting in low sweep efficiency and lower oil recovery. The Lamadian Oilfield in daqing has been waterflooded for 50 years, where various methods have been tried to reduce the high water-cut. This paper presents a novel water conformance control system that has been successfully applied to reduce water-cut and increase the oil production from Lamadian Oilfield. The polymer system containing swelling particles and delayed polymer gelling agents to form plugs and block high permeability channels was tested in the laboratory through sandpack and coreflood experiments at reservoir temperature using injection brine from the Lamadian Oilfield. With injection concentration of polymer ranging between 1200-4500 ppm and crosslinker between 1200-1600 ppm, the experimental tests showed formation of strong plugs in-situ with delayed time of 4-18 days. This system also had low polymer/crosslinker's retention. The lab-measured parameters for rock-fluid interaction were used as input in a history-matched numerical reservoir simulator. Several scenarios with different injection schemes were simulated to investigate the volume of plugs formed, maximum distance travelled by the gelling agents from the injectors before forming plug, and their impact on the surrounding production wells. Simulation results showed that the formation of the plug was the most robust at the front of the crosslinker-polymer system, and the region between the injectors and the front showed formation of secondary plugs by the particles. An optimal scenario was selected for pilot tests. Field tests for 2 well groups with a total of 16 wells started in december 2021 that were successfully completed by April 2022. Field test results show the targeted high-perm channels were blocked, resulting in a significant increase in oil production (up to 15%) in the majority (71%) of the surrounding produ

关键词： Control systems

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limited Entry Liner Completion and Acidizing design with Consideration of reservoir Heterogeneity for MrC Wells

Limited Entry Liner Completion and Acidizing Design with Con...

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2023 Asia Pacific Unconventional resources Symposium, APUr 2023

作者： Liu, Huifeng Jia, Wanting Cui, Longlian Xu, Ning Yang, Guobin Liqiu, Ping Chen, Zhangxin CNPC R&D DIFC Company Limited Dubai United Arab Emirates CNPC Engineering Technology R&D Company Limited Beijing China PetroChina International Investment Australia Pty Ltd Brisbane Australia Department of Chemical and Petroleum Engineering University of Calgary CalgaryAB Canada

ISBN: (纸本)9781959025146

MrC (Maximum reservoir Contact) wells with extra-long laterals (formation contact length > 5000m) are drilled in many oilfields in the world to develop tight and thin reservoirs. LEL (limited Entry Liner) completion and acidizing are an effective technology to stimulate these wells because they distribute the acid uniformly along the long laterals. The design of a distribution of holes in LEL is the key to this technology, especially for reservoirs with high heterogeneity. This study focuses on the optimization of the current LEL completion design strategy by considering the porosity heterogeneity along the lateral and the permeability anisotropy within each segment. Firstly, a model for designing a distribution of holes in LEL is established by incorporating a newly developed model for calculating a post-stimulation equivalent skin factor. Secondly, three LEL completion design strategies are proposed: uniform acid coverage, uniform wormhole length and uniform equivalent skin factor. Thirdly, a real well case is introduced to show the difference between the three strategies in terms of the distribution of holes, generated wormhole length and post-stimulation skin factor. In our new design model, the variances of formation porosity, the differences in acid outlet flow velocity among different segments and the difference in permeability in different directions are considered. This model is used in a horizontal well to achieve uniform post-stimulation equivalent skin factor and the result is compared with those by the other two design strategies. The result from the uniform acid coverage strategy shows that the total number of holes is 198, the length of the generated wormhole is 4.46ft and the equivalent skin factor is -2.88. The result from the uniform wormhole length strategy indicates that fewer holes (totally 135) and a more irregular holes distribution are obtained;the wormhole length is 0.43ft. The result from the uniform equivalent skin factor design strategy s

关键词： Porosity

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3d geomechanical model construction and application of deep shale gas in the Luzhou Block, Sichuan Basin 57

3D geomechanical model construction and application of deep ...

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57th US rock Mechanics/Geomechanics Symposium

作者： Wang, Yuan Yang, Henglin Fu, Li Chen, Gang Yuan, Guangjie Zhang, Heng Wang, Zixin CNPC Engineering Technology R&D Company Limited Beijing China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Beijing China

ISBN: (纸本)9780979497582

deep shale gas with a burial depth of 3500-5000m became an important area for shale gas development in China. The characteristics of the rock's mechanics and the in situ stress have a significant impact on the drilling and fracturing effects of horizontal wells. Finite element simulation is used to build an accurate in situ stress model from the data of acoustic logging, diagnostic fracturing injection test, FMI imaging logging, and stress measurement. The results show that Young's modulus and Poisson's ratio in the Luzhou block change vertically with the deposition time. The Longmaxi reservoir has an abnormally high pore pressure gradient which ranges from 16.7 kPa/m to 21.7 kPa/m. The stress regime of the Luzhou block is primarily strike-slip type, with an overburden pressure gradient of 25.5kPa/m, and a minimum horizontal stress gradient range of 18.8 to 24.5kPa/m. According to wellbore breakouts and acoustic emission experiments of cores, the ratio between σhmax and σhmin is 1.165. The horizontal principal stress of the reservoir increases with the increase of Young's modulus and pore pressure. The conclusion is that high-precision geomechanical models can effectively serve to improve the efficiency of drilling operations, improve the production of single wells and benefit development. © 2023 57th US rock Mechanics/Geomechanics Symposium. All rights reserved.

关键词： Pore pressure

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development and Application of Full Vector Geosteering Comprehensive Analysis Software-OneSteer 11th

Development and Application of Full Vector Geosteering Compr...

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11th International Field Exploration and development Conference, IFEdC 2021

作者： Lin, Wang Wu, dong Liu, Lifeng Zhu, Weixing Xue, Hongzhi CNPC Engineering Technology R&D Company Limited Beijing China PetroChina Research Institute of Petroleum Exploration and Development Beijing China

ISBN: (纸本)9789811921483

Horizontal well technology is a favorable means for the efficient development of "deep, low permeability, offshore, unconventional" and other complex reservoirs, and its key is to improve the drilling rate of the target geological body. Based on the analysis of the business process and requirements of geosteering, aiming at the geological characteristics of China's continental shale, carbonate and glutenite reservoirs, the key technical problems such as geo-steering based stratigraphic structure model modeling, main LWd instrument curve forward modeling, interactive geological model editing, dynamic extraction of stratigraphic parameters, multi-information fusion seismic inversion and so on have been solved, and a full vector geosteering comprehensive analysis software named OneSteer was developed. The software is applied to the field geo-steering analysis of carbonate reservoir in southwest of China and shale reservoirs in Xinjiang oilfields, which improves the drilling encounter rate, reduces the drilling risk, improves the drilling efficiency, and achieves satisfactory results. © 2022, The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd.

关键词： Extraction

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research on Key Materials and Systems of Ultra High Temperature Cement Slurry for Ultra-deep Wells Cementing

Research on Key Materials and Systems of Ultra High Temperat...

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2024 SPE Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2024

作者： Xia, Xiujian Yu, Yongjin Qi, Fengzhong Liu, Huiting Qu, Congfeng CNPC Engineering Technology R&D Company Limited Beijing China National Engineering Research Center for Oil and Gas Drilling and Completion Technology Beijing China

ISBN: (纸本)9781959025269

With the continuous deepening of oil and gas exploration and development, the number of ultra-deep and ultra-high temperature wells is gradually increasing in China. The key materials and systems of cementing slurry are crucial for ensuring the safe construction of wells, effective sealing of cement sheath, and safe production of oil and gas. However, the complex working conditions such as ultra-high temperature pose serious challenges to the materials and systems of cement slurry. Focusing on the technical difficulties of ultra-high temperature cement slurry for deep and ultra-deep wells cementing, the cementing retarder, fluid loss additive, stabilizer, and set cement strength retrogression inhibitor with the temperature resistance of 240 ° C were developed through the technical methods, such as optimizing polymer molecular structure, surface modification of powder materials, and synergistic effects between materials. The novel cement slurry system with the temperature resistance of 240 ° C was formed on basis of the above-mentioned four key additives and their supporting materials. Its comprehensive performance was evaluated. The cement slurry system has the resistance to bottom hole circulating temperature of 240 ° C. After curing at 240 ° C, the settling stability of cement slurry can be controlled within 0.05 g/cm3, the API fluid loss is less than 50 mL, and its thickening time can be adjusted arbitrarily within 200 to 600 min, which is linearly related to the test temperature and retarder dosage. The compressive strength of set cement is 45.8 MPa and 55.2 MPa cured at 240 ° C for 2 d and 28 d, respectively. The comprehensive performance of the cement slurry system is excellent, solving a series of problems such as slurry instability, non-adjustable thickening time, uncontrollable water loss, cement stone cracking, and strength decline under ultra-high temperatures. It can meet the requirements of the ultra-high temperature cementing operations and long-term s

关键词： Cement additives

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The Effect of Polymerization degree of Hydrate Inhibitor on Hydrate Formation: Molecular dynamics Simulations and Experiments 13th

The Effect of Polymerization Degree of Hydrate Inhibitor on ...

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13th International Field Exploration and development Conference, IFEdC 2023

作者： Liao, Bo Wang, Jintang Lv, Kaihe Lv, Xindi Wang, Tong Wang, ren Wang, Jianlong Chen, Longqiao Sun, Jinsheng Shandong Qingdao266580 China Qingdao266580 China CNPC Engineering Technology R&D Company Limited Beijing102206 China Shandong Qingdao266580 China CNPC Offshore Engineering Company Limited Beijing100028 China

ISBN: (纸本)9789819702671

Natural methane hydrates are estimated to be the largest source of unexploited hydrocarbon fuel. However, there are many difficulties in drilling for natural gas hydrates production, among which inhibiting hydrate generation is an important issue. The conventional thermodynamic inhibitors have difficulties such as large dosages and are not environmentally friendly, while the widely used kinetic inhibitors also suffer from failure with high subcooling. Thus, it is urgent to develop new efficient hydrate inhibitors. Molecular design of hydrate inhibitor molecules using molecular simulations is one of the most common tools used. However, it is challenging to reproduce experimental-scale hydrate inhibitor fractions at the molecular scale. Thus, many studies have only investigated the effect of a minimal number of repeating units in an inhibitor on hydrate stability, leading to conclusions about the effects of various functional groups on hydrate stability. In contrast, a selection of the number of repeating units (polymerization degree, N) in the molecular structure of polymeric hydrate inhibitors has rarely been discussed. In this work, polymer PVP-N with different N was established based on NVP. The effect of a polymer molecular weight on hydrate formation was investigated. The results show that the different N in PVP has a significant effect on a diffusion coefficient of water molecules. A smaller N in PVP is more likely to inhibit hydrate formation during the phase of nucleation, but its effect is significantly weakened during the phase of formation. This study helps us to understand the effect of a polymer molecular weight on the performance of hydrate inhibitors and select an appropriate number of repeating units in molecular modeling, which dramatically reduces the difficulty of designing the molecular structures of hydrate inhibitors and other drilling fluid treatment agents, clarifies the mechanism of action of hydrate inhibitors and other drilling fluid treatm

关键词： Molecular structure

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Numerical Simulation of Long-term Stability of Irregular Underground Salt Caverns under Alternating Loads 58

Numerical Simulation of Long-term Stability of Irregular Und...

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58th US rock Mechanics / Geomechanics Symposium 2024, ArMA 2024

作者： Chang, Zhi Xia, Yan Kun, dai Liu, Tianen Zhang, Qi Ban, Fansheng CNPC Engineering Technology R&D Company Limited Beijing China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Beijing China NO.1 Drilling Engineering Company BHDC Tianjin China CNPC Engineering Technology R&D Company Limited Beijing China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Beijing China

ISBN: (纸本)9798331305086

The proportion of green energy, such as photovoltaic and wind power, in power generation is increasing year by year. However, green energy often exhibits significant periodic fluctuations. Therefore, it is imperative to construct a large number of compressed air energy storage facilities to meet the daily demand for peak power regulation. Utilizing the dissolved cavity of salt rock layers to build underground salt cavern energy storage presents an economical and reliable solution due to the low permeability and self-repairing properties of salt rock. Nevertheless, most salt rock layers in China contain mudstone interlayers, which pose challenges in accurately controlling the shape of salt caverns during the water injection process within the dissolved cavity. This often results in irregularities, unevenness, and large curvatures near the mudstone interlayer within the cavity shape. Such irregularities on the inner wall of cavities pose a significant threat to long-term stability as they are prone to stress concentration and collapse. The present study establishes a sophisticated three-dimensional geometric model based on the geometry and geological conditions of underground salt caverns in the Hengyang area. Utilizing COMSOL, a numerical simulation is conducted to investigate the long-term creep stability of irregularly shaped salt caverns over a period of 30 years. The impact of salt cavern geometry on long-term stability is quantitatively assessed through key parameters such as volume shrinkage rate, plastic deformation, and stress concentration areas. Copyright 2024 ArMA, American rock Mechanics Association.

关键词： Caves

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Nanoparticles Improved Sedimentation Stability of Oil-Based Completion Fluids While drilling Ultra-deep Wells

Nanoparticles Improved Sedimentation Stability of Oil-Based ...

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2023 Abu dhabi International Petroleum Exhibition and Conference, AdIP 2023

作者： Yan, L.L. Wang, J.H. Ni, X.X. Sun, J.S. Wang, r. Zhang, J.Q. Cui, X.B. CNPC Engineering Technology R&D Company Limited Beijing China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Beijing China

ISBN: (纸本)9781959025078

The deep and ultra-deep oil and gas resources are important sources to meet the increasing oil and gas demands. But they are difficult to be explored because their buried geological conditions are extremely complex, such as high temperature (HT), high pressure (HP), thick salt and gypsum beds and borehole collapse. Oil-based drilling fluid (OBdF) is the preferred drilling fluid for ultra-deep wells due to its better wellbore stability and higher lubricity than water-based drilling fluid. Meanwhile, the oil-based completion fluid (OBCF) is also the first choice for operators because it can be turned directly by the OBdF, which is convenient and reusable. However, barite sag is often encountered because the completion fluid is required to be static for 7 to 15 days at a high temperature of more than 180°C, which results in serious problems, pipe sticking, density variation and well control problems, in ultra-deep wells. It is urgent to improve the sedimentation stability of OBCF while drilling the ultra-deep wells. In this paper, a modified nano-silica stabilizer was prepared to improve the sedimentation stability of OBCF. Its dispersity in a water-in-oil (W/O) emulsion with an oil-water ratio of 80:20 was observed by a cryo-scanning electron microscope and the viscosity at low shear rates was also tested. Then OBCF formulations with different densities were developed and modified by the prepared nano-silica stabilizer. The rheology and sedimentation stability were evaluated on HTHP rheometer and sedimentometer, respectively. The HTHP sedimentometer can work at a pressure up to 105 MPa and a temperature up to 300°C. results indicated that the novel nano-silica stabilizer could disperse stably in the water-oil interface and in the oil phase. The viscosity of the W/O emulsion at low shear rates was significantly increased after adding the nano-stabilizer. Meanwhile, the HTHP rheology and sedimentation stability of the high-density OBCF were improved by the nano-stabiliz

关键词： Scanning electron microscopy

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Pore Pressure Prediction in deep Complex Formations Based on Well-Seismic Combination 58

Pore Pressure Prediction in Deep Complex Formations Based on...

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58th US rock Mechanics / Geomechanics Symposium 2024, ArMA 2024

作者： Zixuan, Yang Chenxi, Ye Qian, Wang Wenbao, Zhai Peng, Tan Zhaowei, Chen CNPC Engineering Technology R&D Company Limited Beijing China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Beijing China

ISBN: (纸本)9798331305086

With the development of oil and gas drilling technology, oil and gas exploration and development have moved towards deep to ultra-deep layers. due to its deep burial depth, deep formations face various challenges such as high temperature, high pressure, and high stress. The prediction of formation pore pressure is a core factor of drilling design optimization and risk prevention. In order to improve the prediction accuracy on the basis of existing pre-drilling formation pore pressure prediction methods, the logging data and actual drilling data of the drilled wells were combined with the seismic data. In this paper, a set of high accuracy pore pressure prediction method based on well-seismic combination are formed by using the interval-controlled interval velocity modeling method and the well-controlled interval velocity correction method. The method is applied to a deep well in Tarim Basin. This well was designed to exceed a depth of 8,000 meters. The predicted pore pressure coefficient of the well is between 1.04 and 1.22 g/cm3. The measured pore pressure coefficient after drilling was between 1.07 and 1.22 g/cm3. Actual analysis has demonstrated the accuracy and reliability of pore pressure prediction, providing support for pre-drilling pressure forecasts. Copyright 2024 ArMA, American rock Mechanics Association.

关键词： Pore pressure

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The Successful Application of Expansion Tube technology in the Bongor Basin of Chad 13th

The Successful Application of Expansion Tube Technology in t...

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13th International Field Exploration and development Conference, IFEdC 2023

作者： Zhong, Zhao Li, Xiao-Gang Liu, Ji-Tong Ji, Fei Li, Gang-Lu Jia, Tao Liu, Chen-Chao Zhang, Guo-Bin Liu, Shan-Shan CNPC Engineering Technology R&D Company Limited Beijing102206 China China National Oil and Gas Exploration and Development Corporation Beijing100034 China CNPC Bohai Drilling Engineering Company Limited Tianjin300452 China

ISBN: (纸本)9789819702558

The Bongor is the main basin for increasing storage and production in the cnpc Chad. With the continuous deepening of development, underground safety operations face the following problems: the inability to effectively seal the gas layer in the overlying strata of the basement, the high risk of secondary completion of the basement gas injection well, and the poor stability of the wellbore in the M group shale formation. In response to the bottleneck problems faced by underground operations, geological, drilling, logging, and other data were analyzed and sorted. Based on the expansion tube technology, the safety sealing technology for high-pressure gas cap in basement, secondary completion technology for basement gas injection wells, and openhole sealing technology for expansion tubes were optimized and formed. They were successfully applied for the first time in the Bongor Basin, achieving a daily gas injection volume of 2000 Nm3, shortening the construction cycle, improving wellbore quality, and reducing complex underground risks, Subsequently, it will be widely promoted and applied as a mature technology, supporting the efficient development of the Bongor Basin. At the same time, the expansion tube technology has a demonstration effect on the development of similar oil fields due to its good practical functions and application value [1–6]. © The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd. 2024.

关键词： Gases

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