Evaluation of the Potentials for Adapting the Multistage Hydraulic Fracturing Technology in Tight Carbonate Reservoir

2019 ◽  
Author(s):  
Omar Al-Fatlawi ◽  
Mofazzal Hossain ◽  
Neha Patel ◽  
Akim Kabir
Keyword(s):  
Hydraulic Fracturing ◽  
Carbonate Reservoir ◽  
Multistage Hydraulic Fracturing ◽  
Tight Carbonate

Mechanical Layering: Implications for Hydraulic Fracturing in an Unconventional Tight Carbonate Reservoir in Abu Dhabi, UAE

2014 ◽  
Author(s):  
Manhal Sirat ◽  
Xing Zhang ◽  
Janelle Simon ◽  
Aurifullah Vantala ◽  
Magdalena Povstyanova
Keyword(s):  
Hydraulic Fracturing ◽  
Carbonate Reservoir ◽  
Abu Dhabi ◽  
Tight Carbonate

First Multistage Fracturing of a Horizontal Well Drilled in a Tight Carbonate Reservoir in UAE

2021 ◽  
Vol 73 (06) ◽  
pp. 58-59
Author(s):  
Chris Carpenter
Keyword(s):  
Hydraulic Fracturing ◽  
Horizontal Well ◽  
Lessons Learned ◽  
Carbonate Reservoir ◽  
Thin Layers ◽  
Abu Dhabi ◽  
Total Production ◽  
Main Challenge ◽  
Horizontal Length ◽  
Tight Carbonate

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 203226, “First Multistage Fracturing of Horizontal Well Drilled in a Conventional Tight Carbonate Reservoir in an Onshore Field in the UAE: Challenges and Lessons Learned,” by Muhammad Aftab, SPE, Noor Talib, and Maad Subaihi, ADNOC, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. The reservoir upon which this case study is focused is a tight, low-permeability carbonate reservoir with thin layers. The objective of the field case was to increase and sustain productivity of a pilot well consisting of an openhole completion. The complete paper summarizes the design processes, selection criteria, challenges, and lessons learned during design and execution phases. The study may provide a potential approach for selecting the proper hydraulic fracturing method and technique in similar cases. Introduction Reservoir X is divided into six layers. Layers X-3 through X-6 have reasonable porosity development; valid pressure points exist in X-3 and X-6. Pumpout was performed while collecting samples from X-3 and X-6, followed by short buildups. Production-logging-tool measurement was performed and found two major oil-producing layers across X-3 (60% of total production) and X-6 (40% of total production). The remaining intervals of the perforation were almost inactive. Petrophyscial and testing results of vertical Well A resulted in a decision to drill a horizontal oil producer (Well B) through Layer X-3. Well B was steered with a 2,220-ft horizontal length, out of which 1,930 ft was inside X-3 and 290 ft were above X-3 be-cause of a fault throw of 16 ft true vertical depth. The well was steered with a horizontal length of 2,080 ft in X-6. Well B was completed with a 3½-in. completion and horizontal section as an openhole. Matrix stimulation using coiled tubing was performed with 15% hydrochloric acid in Well B. The well ceased to flow after 2 weeks of declining production. Rapid pressure depletion was observed in Well B. Localized depletion around the wellbore was anticipated because of poor matrix/matrix connectivity. After comprehensive studies and risk assessments, the decision was made to recomplete Well B with a cemented fracturing string to perform hydraulic fracturing with the plug-and-perf technique. This technique will allow flexibility of stage count and stage spacing and a multi-cluster design to maximize the stimulated reservoir volume (SRV) along the upper, middle, and lower layers. In addition, the operator and service provider collaborated to enhance this design through a zero-overflush technique with diverting agents. The complete paper provides a detailed discussion of the core measurement and 1D mechanical Earth model used in the hydraulic fracturing design. Hydraulic Fracturing Design The main challenge in fracturing Well B was to ensure that the fracture generated is contained within the reservoir. Well B is completed in two layers (X-3 and X-6). The bottom part of the well is in X-6 and close to another underlying reservoir (Fig. 1).

Technology Focus: Hydraulic Fracturing Operations (June 2021)

2021 ◽  
Vol 73 (06) ◽  
pp. 55-55
Author(s):  
Chris Carpenter
Keyword(s):  
Hydraulic Fracturing ◽  
Elevated Pressure ◽  
Pilot Scale ◽  
Carbonate Reservoir ◽  
Great Promise ◽  
Area Of Interest ◽  
Fracturing Fluids ◽  
Wellbore Pressure ◽  
Tight Carbonate ◽  
Online Library

This issue marks the debut of the Hydraulic Fracturing Operations feature in JPT. While hydraulic fracturing has long been a feature topic, this year, we are branching this major area of interest into both this feature and a Hydraulic Fracturing Modeling feature, which will appear in the November issue of the magazine. For this issue, reviewer Nabila Lazreq of ADNOC has selected three papers that reflect industry efforts to achieve new goals in production and sustainability. Paper 201450 investigates the potential of natural gas (NG) foam fracturing fluid to reduce the major water requirements seen in stimulation. The authors write that such requirements can be reduced up to 80% in some cases by the use of NG foams. Although modeling is used to reach their conclusions, the authors point out that NG foam fracturing fluids have great promise in operational scenarios in areas such as the Duvernay Shale. Paper 203226 reviews the challenges and conclusions reached by an operator implementing multistage fracturing for the first time in a horizontal well in a UAE tight carbonate reservoir. A cross-disciplinary approach proved effective when conventional stimulation methods were not successful in this challenging formation. Finally, paper 201611 returns to the topic of NG foams, investigating their utility as an alternative to fracturing fluids composed of nitrogen and carbon-dioxide foams. The pilot-scale study leads the authors to conclude that NG foams are effective fracturing fluids that exhibit stable viscosity at elevated pressure and temperature conditions. We hope that you enjoy the inaugural Hydraulic Fracturing Operations feature. Feel free to access the complete papers, and others that reflect recent achievements of SPE conference authors, in the OnePetro online library. Recommended additional reading at OnePetro: www.onepetro.org. SPE 204190 Optimization of Coal-Seam Connectivity by Multiseam Pinpoint Fracturing Operations in the Walloons Coal Measures, Surat Basin by Vibhas J. Pandey, ConocoPhillips, et al. SPE 204140 An Eagle Ford Case Study: Monitoring Fracturing Propagation Through Sealed Wellbore Pressure Monitoring by Kourtney Brinkley, Devon Energy, et al. SPE 202760 Tight Oil From Shale Rock in UAE: A Success Story of Unconventional Fracturing by Nabila Lazreq, ADNOC, et al.

Novel Coiled Tubing Perforation Approach Enables Efficient Multistage Hydraulic Fracturing Operations in a Horizontal Well in Oman

2016 ◽  
Author(s):  
Ali Al-Ghaithi ◽  
Fahad Alawi ◽  
Ernest Sayapov ◽  
Ehab Ibrahim ◽  
Najet Aouchar ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Horizontal Well ◽  
Multistage Hydraulic Fracturing ◽  
Coiled Tubing

Stress perturbation caused by multistage hydraulic fracturing: Implications for deep fault reactivation

2021 ◽  
Vol 141 ◽  
pp. 104704
Author(s):  
Mengke An ◽  
Fengshou Zhang ◽  
Egor Dontsov ◽  
Derek Elsworth ◽  
Hehua Zhu ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Fault Reactivation ◽  
Deep Fault ◽  
Multistage Hydraulic Fracturing

Increasing the Productivity of Horizontal Wells Through Multistage Hydraulic Fracturing Using a Working Fluid Based on a New Biopolymer System

2021 ◽  
Author(s):  
Nikolay Mikhaylovich Migunov ◽  
Aleksey Dmitrievich Alekseev ◽  
Dinar Farvarovich Bukharov ◽  
Vadim Alexeevich Kuznetsov ◽  
Aleksandr Yuryevich Milkov ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Russian Federation ◽  
Oil Production ◽  
Horizontal Wells ◽  
Working Fluid ◽  
High Tech ◽  
Executive Order ◽  
Bazhenov Formation ◽  
Multistage Hydraulic Fracturing ◽  
The Russian Federation

Abstract According to the US Energy Agency (EIA), Russia is the world leader in terms of the volume of technically recoverable "tight oil" resources (U.S. Department of Energy, 2013). To convert them into commercial production, it is necessary to create cost-effective development technologies. For this purpose, a strategy has been adopted, which is implemented at the state level and one of the key elements of which is the development of the high-tech service market. In 2017, the Minister of Energy of the Russian Federation, in accordance with a government executive order (Government Executive Order of the Russian Federation, 2014), awarded the Gazprom Neft project on the creation of a complex of domestic technologies and high-tech equipment for developing the Bazhenov formation with the national status. It is implemented in several directions and covers a wide range of technologies required for the horizontal wells drilling and stimulating flows from them using multi-stage hydraulic fracturing (MS HF) methods. Within the framework of the technological experiment implemented at the Palyanovskaya area at the Krasnoleninskoye field by the Industrial Integration Center "Gazpromneft - Technological Partnerships" (a subsidiary of Gazprom Neft), from 2015 to 2020, 29 high-tech wells with different lengths of horizontal wellbore were constructed, and multistage hydraulic fracturing operations were performed with various designs. Upon results of 2020, it became possible to increase annual oil production from the Bazhenov formation by 78 % in comparison with up to 100,000 tons in 2019. The advancing of development technologies allowed the enterprise to decrease for more than twice the cost of the Bazhenov oil production from 30 thousand rubles per ton (69$/bbl) at the start of the project in 2015 to 13 thousand rubles (24$/bbl) in 2020. A significant contribution to the increase in production in 2020 was made by horizontal wells, where MS HF operations were carried out using an experimental process fluid, which is based on the modified Si Bioxan biopolymer. This article is devoted to the background of this experiment and the analysis of its results.

Using Logging and Seismic Data to Identify Boundaries Between Different OWC Units in a Deepwater Carbonate Reservoirs

2021 ◽  
Author(s):  
Kangxu Ren ◽  
Junfeng Zhao ◽  
Jian Zhao ◽  
Xilong Sun
Keyword(s):  
Seismic Data ◽  
Carbonate Rocks ◽  
Carbonate Reservoir ◽  
Carbonate Reservoirs ◽  
Sedimentary Process ◽  
Core Samples ◽  
Tight Carbonate ◽  
Porosity And Permeability ◽  
Seismic Sections ◽  
Parameters Inversion

Abstract At least three very different oil-water contacts (OWC) encountered in the deepwater, huge anticline, pre-salt carbonate reservoirs of X oilfield, Santos Basin, Brazil. The boundaries identification between different OWC units was very important to help calculating the reserves in place, which was the core factor for the development campaign. Based on analysis of wells pressure interference testing data, and interpretation of tight intervals in boreholes, predicating the pre-salt distribution of igneous rocks, intrusion baked aureoles, the silicification and the high GR carbonate rocks, the viewpoint of boundaries developed between different OWC sub-units in the lower parts of this complex carbonate reservoirs had been better understood. Core samples, logging curves, including conventional logging and other special types such as NMR, UBI and ECS, as well as the multi-parameters inversion seismic data, were adopted to confirm the tight intervals in boreholes and to predicate the possible divided boundaries between wells. In the X oilfield, hundreds of meters pre-salt carbonate reservoir had been confirmed to be laterally connected, i.e., the connected intervals including almost the whole Barra Velha Formation and/or the main parts of the Itapema Formation. However, in the middle and/or the lower sections of pre-salt target layers, the situation changed because there developed many complicated tight bodies, which were formed by intrusive diabase dykes and/or sills and the tight carbonate rocks. Many pre-salt inner-layers diabases in X oilfield had very low porosity and permeability. The tight carbonate rocks mostly developed either during early sedimentary process or by latter intrusion metamorphism and/or silicification. Tight bodies were firstly identified in drilled wells with the help of core samples and logging curves. Then, the continuous boundary were discerned on inversion seismic sections marked by wells. This paper showed the idea of coupling the different OWC units in a deepwater pre-salt carbonate play with complicated tight bodies. With the marking of wells, spatial distributions of tight layers were successfully discerned and predicated on inversion seismic sections.

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