A Case Study of Flexible/Expandable and Self-Healing Cement for Ensuring Zonal Isolation in a Shallow, Hydraulically Fractured Gas Well, Onshore Thailand

2015 ◽  
Author(s):  
J.A. Vargas Bermea ◽  
S. Taoutaou ◽  
K. Olutimehin ◽  
M. Vinaipanit ◽  
S. Ashraf ◽  
...  
Keyword(s):  
Self Healing ◽  
Gas Well ◽  
Zonal Isolation

Solidifying Mud Cake to Improve Cementing Quality of Shale Gas Well: A Case Study

2015 ◽  
Vol 8 (1) ◽  
pp. 149-154 ◽  
Author(s):  
Jun Gu ◽  
Ju Huang ◽  
Su Zhang ◽  
Xinzhong Hu ◽  
Hangxiang Gao ◽  
...  
Keyword(s):  
Shale Gas ◽  
Calcium Silicate Hydrate ◽  
Drilling Fluid ◽  
Cement Slurry ◽  
Gas Well ◽  
Safety Requirements ◽  
Mud Cake ◽  
Gas Bearing

The purpose of this study is to improve the cementing quality of shale gas well by mud cake solidification, as well as to provide the better annular isolation for its hydraulic fracturing development. Based on the self-established experimental method and API RP 10, the effects of mud cake solidifiers on the shear strength at cement-interlayer interface (SSCFI) were evaluated. After curing for 3, 7, 15 and 30 days, SSCFI was remarkably improved by 629.03%, 222.37%, 241.43% and 273.33%, respectively, compared with the original technology. Moreover, the compatibility among the mud cake solidifier, cement slurry, drilling fluid and prepad fluid meets the safety requirements for cementing operation. An application example in a shale gas well (Yuanye HF-1) was also presented. The high quality ratio of cementing quality is 93.49% of the whole well section, while the unqualified ratio of adjacent well (Yuanba 9) is 84.46%. Moreover, the cementing quality of six gas-bearing reservoirs is high. This paper also discussed the mechanism of mud cake solidification. The reactions among H3AlO42- and H3SiO4- from alkali-dissolved reaction, Na+ and H3SiO4- in the mud cake solidifiers, and Ca2+ and OH- from cement slurry form the natrolite and calcium silicate hydrate (C-S-H) with different silicate-calcium ratio. Based on these, SSCFI and cementing quality were improved.

Case Study: Zonal Isolation Challenges in the Midway-Sunset Field of the San Joaquin Valley

2015 ◽  
Author(s):  
Juan José Gomez Valadez ◽  
Larry Todd ◽  
Matthew Cleveland ◽  
Travis Clark ◽  
Matt Kruse
Keyword(s):  
San Joaquin Valley ◽  
Zonal Isolation

Technology Focus: Cementing and Zonal Isolation (May 2021)

2021 ◽  
Vol 73 (05) ◽  
pp. 65-65
Author(s):  
Gunnar DeBruijn
Keyword(s):  
National Laboratory ◽  
Self Healing ◽  
Evaluation Tool ◽  
Initial State ◽  
Los Alamos National Laboratory ◽  
Successful Case ◽  
Managed Pressure Drilling ◽  
Zonal Isolation ◽  
Primary Cementing ◽  
Technology Focus

Wow! What a year it has been! We have experienced enormous upheavals in our professional and social circles and wholescale changes in the way that we interact with each other. As engineers, though, we recognize that in every challenge there is an opportunity. I have been lucky to attend SPE online events, including a happy hour and a webinar on geothermal energy. As we witness a shift to renewable energy, I note that 2020 SPE President Shauna Noonan highlighted that our SPE professional expertise in the subsurface will be needed to both maintain existing energy production and develop new sources of energy. Cementing, zonal isolation, and well integrity continue to be an important piece of the puzzle. This year, in the presence of enormous challenges, the selected papers demonstrate step changes both in efficiency and in the results of cementing operations. Managed-pressure cementing extends the benefits of managed-pressure drilling, and a successful case is described in paper OTC 30481. Last year, we read about offline cementing in North America. Offline cementing continues to increase rig efficiency, and wellhead equipment that enables offline cementing is described in paper SPE 202439. Improving cementing results by enabling casing rotation with rotating cement heads is discussed in paper SPE 198970. Research that will enable future successful changes also continues. Although not summarized in this edition, extra reading is recommended for interesting discussions on proving shale as a barrier (SPE 200755), cement properties and initial state of stress in confined pressure conditions (SPE 201770), and the evaluation of neutron logging as a possible cement evaluation tool (SPE 202973). As an industry, we also continue to investigate materials that will provide effective isolation in the annulus. Papers about self-healing systems (SPE 203174), epoxy (SPE 202648), and expanding metal sealing systems (SPE 203354) are also recommended as extra reading. Although it has been a challenging year, operational improvements, research, and material investigation continue to provide engineering opportunities in cementing and zonal isolation. Recommended additional reading at OnePetro: www.onepetro.org. SPE 200755 - Innovative One-Trip System Helps Qualify Creeping Shale as Permanent Barrier for Plug and Abandonment of Wells on the Gyda Field by Thore Andre Stokkeland, Archer, et al. SPE 201770 - Laboratory Measurement of Cement Stress Before, During, and After Curing Under Undrained Condition With Constant Hydrostatic Pressure by Meng Meng, Los Alamos National Laboratory, et al. SPE 202973 - Potential Usage of Neutron Logging Technology for Casing Cement Evaluation—Feasibility Study by Espen Dommersnes, University of Stavanger, et al. SPE 203174 - A Game-Changing Technology for Cementing in Highly Deviated and Horizontal Wells Using Interactive Mud-Sealing Cement System by Choosak Orprasert, Mubadala Petroleum, et al. SPE 202648 - Primary Cementing Using Epoxy Resins as Additive: Experimental and Application by Khawlah Abdulaziz Alanqari, Saudi Aramco, et al.

The Research and Application of Cementing Isolation Technology in High Porosity and Permeability of Developed Clastic Rock Reservoir in Tarim Basin

2021 ◽  
Author(s):  
Hongtao Liu ◽  
Zhengqing Ai ◽  
Jingcheng Zhang ◽  
Zhongtao Yuan ◽  
Jianguo Zeng ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Water Layer ◽  
High Porosity ◽  
Self Healing ◽  
Cement Slurry ◽  
Clastic Rock ◽  
Pump Rate ◽  
Porosity And Permeability ◽  
Zonal Isolation ◽  
High Pump

Abstract The average porosity and permeability in the developed clastic rock reservoir in Tarim oilfield in China is 22.16% and 689.85×10-3 μm2. The isolation layer thickness between water layer and oil layer is less than 2 meters. The pressure of oil layer is 0.99 g/cm3, and the pressure of bottom water layer is 1.22 g/cm3, the pressure difference between them is as bigger as 12 to 23 MPa. It is difficult to achieve the layer isolation between the water layer and oil layer. To solve the zonal isolation difficulty and reduce permeable loss risk in clastic reservoir with high porosity and permeability, matrix anti-invasion additive, self-innovate plugging ability material of slurry, self-healing slurry, open-hole packer outside the casing, design and control technology of cement slurry performance, optimizing casing centralizer location technology and displacement with high pump rate has been developed and successfully applied. The results show that: First, the additive with physical and chemical crosslinking structure matrix anti-invasion is developed. The additive has the characteristics of anti-dilution, low thixotropy, low water loss and short transition, and can seal the water layer quickly. Second, the plugging material in the slurry has a better plugging performance and could reduce the permeability of artificial core by 70-80% in the testing evaluation. Third, the self-healing cement slurry system can quickly seal the fracture and prevent the fluid from flowing, and can ensuring the long-term effective sealing of the reservoir. Fourth, By strict control of the thickening time (operation time) and consistency (20-25 Bc), the cement slurry can realize zonal isolation quickly, which has achieved the purpose of quickly sealing off the water layer and reduced the risk of permeable loss. And the casing centralizers are used to ensure that the standoff ratio of oil and water layer is above 67%. The displacement with high pump rate (2 m3/min, to ensure the annular return velocity more than 1.2 m/s) can efficiently clean the wellbore by diluting the drilling fluid and washing the mud cake, and can improve the displacement efficiency. The cementing technology has been successfully applied in 100 wells in Tarim Oilfield. The qualification rate and high quality rate is 87.9% and 69% in 2019, and achieve zone isolation. No water has been produced after the oil testing and the water content has decreased to 7% after production. With the cementing technology, we have improved zonal isolation, increased the crude oil production and increased the benefit of oil.

A Case Study of Hydraulic Fracturing Monitoring in Shale Gas Well Based on DAS

2021 ◽  
Author(s):  
S. An ◽  
X. Liang ◽  
G. Yu ◽  
D. Li ◽  
J. Wu ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Shale Gas ◽  
Gas Well

Subsea Gas Well Late Life Restart Lesson Learned: Failure Analysis and Operating Strategy

2021 ◽  
Author(s):  
Song Wang ◽  
Lawrence Khin Leong Lau ◽  
Wu Jun Tong ◽  
Kun An ◽  
Jiang Nan Duan ◽  
...  
Keyword(s):  
Failure Analysis ◽  
Late Life ◽  
Flow Assurance ◽  
Gas Well ◽  
Subsea Pipeline ◽  
Operating Strategy ◽  
Root Cause ◽  
Financial Impacts ◽  
Transient Multiphase Flow

Abstract This paper elucidates the importance of flow assurance transient multiphase modelling to ensure uninterrupted late life productions. This is discussed in details through the case study of shut-in and restart scenarios of a subsea gas well (namely Well A) located in South China Sea region. There were two wells (Well A and Well B) producing steadily prior to asset shut-in, as a requirement for subsea pipeline maintenance works. However, it was found that Well A failed to restart while Well B successfully resumed production after the pipeline maintenance works. Flow assurance team is called in order to understand the root cause of the failed re-start of Well A to avoid similar failure for Well B and other wells in this region. Through failure analysis of Well A, key root cause is identified and associated operating strategy is proposed for use for Well B, which is producing through the same subsea infrastructure. Transient multiphase flow assurance model including subsea Well A, subsea Well B, associated spools, subsea pipeline and subsea riser is developed and fully benchmarked against field data to ensure realistic thermohydraulics representations of the actual asset. Simulation result shows failed restart of Well A and successful restart of Well B, which fully matched with field observations. Further analysis reveals that liquid column accumulated within the wellbore of Well A associates with extra hydrostatic head which caused failed well restart. Through a series of sensitivity analysis, the possibility of successful Well A restart is investigated by manipulating topsides back pressure settings and production flowrates prior to shut-in. These serve as a methodology to systematically analyze such transient scenario and to provide basis for field operating strategy. The analysis and strategy proposed through detailed modelling and simulation serves as valuable guidance for Well B, should shut-in and restart operation is required. This study shows the importance of modelling prior to late life field operations, in order to avoid similar failed well restart, which causes significant production and financial impacts.

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