Lessons Learned From a Subsurface, Well Completion, and Hydraulic Fracturing Perspective for a Multiwell Liquid-Rich Resource Play in West China

2015 ◽  
Author(s):  
Jing Zhang ◽  
Xu Jiangwen ◽  
Yuan Liu ◽  
Tobias Judd ◽  
Hai Liu ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Lessons Learned ◽  
West China ◽  
Well Completion

Novel Approach for Selecting Well Candidates and Appropriate Design of Hydraulic Fracturing in Challenging Reservoirs

2021 ◽  
Author(s):  
Muhammad Mirza ◽  
Hassan Al Saadi ◽  
Ricardo Sebastian Trejo ◽  
Rifat Kayumov ◽  
Ahmed Hilal
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Recovery ◽  
Selection Process ◽  
Lessons Learned ◽  
Candidate Selection ◽  
Significant Heterogeneity ◽  
Water Contact ◽  
Well Completion ◽  
Medium Permeability ◽  
Selection Of

Abstract Karim and Haradh reservoirs within the Karim Small Fields (KSF) cluster in the South of the Sultanate of Oman are characterized by low to medium permeability and significant heterogeneity and contain medium to heavy crude oil. Reservoir depths are in the range of 1500 to 2000 m and productive areas are relatively small (around 2 km2 per field). Over the past 10 years, fields development did not result in sustained oil production despite the close well spacing. Geological and reservoir studies indicated that this is mainly due to the heterogeneity, lack of reservoir continuity and presence of significant wellbore damage in most wells. Accordingly, the KSF operator initiated an appraisal campaign focusing on hydraulic fracturing to stimulate the producing wells and improve the extension of their drainage areas. This campaign resulted in significant improvement in well productivity and the analysis of results indicates good potential for improving the ultimate oil recovery from these reservoirs. Although the results from hydraulic fracturing campaign are encouraging, they also indicate that appropriate selection of well candidates, key parameters in the fracturing procedure, effects of well completion and impact of well age are very important for successful oil gain. As a result, a comprehensive procedure for selecting and ranking candidate wells for hydraulic fracturing in Karim and Haradh formations has been developed. The procedure includes assessing the impacts of key properties such as fracture height, depth of oil-water contact, thickness of oil column, and distance to faults. In addition, the lessons learned from the previous appraisal campaign will contribute to achieving optimum fracture geometry in future campaigns. The candidate selection workflow involves understanding the geology, geomechanics, and petrophysics of the wells in which a fracturing operation was performed previously in different formations in KSF. More than 20 existing wells were screened through the candidate selection process using a clear workflow to incorporate all the relevant aspects of the selection criteria. The outcome of the candidate selection phase led to selection of the best wells for fracturing operations in the Karim and Haradh formations. The improvements on the fracturing design have been followed to obtain the optimum fracturing design for the selected wells.

The Use of Tracer Technologies for Well Monitoring with Multi-Stage Hydraulic Fracturing on Bolshetirskoye Oil Field

2021 ◽  
Author(s):  
Ivan Krasnov ◽  
Oleg Butorin ◽  
Igor Sabanchin ◽  
Vasiliy Kim ◽  
Sergey Zimin ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Recovery ◽  
Hydraulic Fracture ◽  
Horizontal Wells ◽  
Pilot Project ◽  
Oil Field ◽  
Well Completion ◽  
Construction Design ◽  
Multi Stage ◽  
Urgent Task

Abstract With the development of drilling and well completion technologies, multi-staged hydraulic fracturing (MSF) in horizontal wells has established itself as one of the most effective methods for stimulating production in fields with low permeability properties. In Eastern Siberia, this technology is at the pilot project stage. For example, at the Bolshetirskoye field, these works are being carried out to enhance the productivity of horizontal wells by increasing the connectivity of productive layers in a low- and medium- permeable porous-cavernous reservoir. However, different challenges like high permeability heterogeneity and the presence of H2S corrosive gases setting a bar higher for the requirement of the well construction design and well monitoring to achieve the maximum oil recovery factor. At the same time, well and reservoir surveillance of different parameters, which may impact on the efficiency of multi-stage hydraulic fracturing and oil contribution from each hydraulic fracture, remains a challenging and urgent task today. This article discusses the experience of using tracer technology for well monitoring with multi-stage hydraulic fracturing to obtain information on the productivity of each hydraulic fracture separately.

Malaysia's First Successful Implementation of Sand Consolidation Technology as a Primary Sand Control Method Executed during the Drilling Phase: Success Story and Lessons Learned

2021 ◽  
Author(s):  
Nadiah Kamaruddin ◽  
Nurfuzaini A Karim ◽  
M Ariff Naufal Hasmin ◽  
Sunanda Magna Bela ◽  
Latief Riyanto ◽  
...  
Keyword(s):  
Control Method ◽  
Movement Control ◽  
Lessons Learned ◽  
Successful Implementation ◽  
Success Story ◽  
Control Solution ◽  
Consolidation Process ◽  
Execution Plan ◽  
Well Completion ◽  
Sand Control

Abstract Field A is a mature hydrocarbon-producing field located in eastern Malaysia that began producing in 1968. Comprised of multistacked reservoirs at heights ranging from 4,000 to 8,000 ft, they are predominantly unconsolidated, requiring sand exclusion from the start. Most wells in this field were completed using internal gravel packing (IGP) of the main reservoir, and particularly in shallower reservoirs. With these shallower reservoirs continuously targeted as good potential candidates, identifying a sustainable sand control solution is essential. Conventional sand control methods, namely IGP, are normally a primary choice for completion; however, this method can be costly, which requires justification during challenging economic times. To combat these challenges, a sand consolidation system using resin was selected as a primary completion method, opposed to a conventional IGP system. Chemical sand consolidation treatments provide in situ sand influx control by treating the incompetent formation around the wellbore itself. The initial plan was to perform sand consolidation followed by a screenless fracturing treatment; however, upon drilling the targeted zone and observing its proximity to a water zone, fracturing was stopped. With three of eight zones in this well requiring sand control, a pinpoint solution was delivered in stages by means of a pump through with a packer system [retrievable test treat squeeze (RTTS)] at the highest possible accuracy, thus ensuring treatment placement efficiency. The zones were also distanced from one another, requiring zonal isolation (i.e., mechanical isolation, such as bridge plugs, was not an option) as treatments were deployed. While there was a major challenge in terms of mobilization planning to complete this well during the peak of a movement control order (MCO) in Malaysia, optimal operations lead to a long-term sand control solution. Well unloading and test results upon well completion provided excellent results, highlighting good production rates with zero sand production. The groundwork processes of candidate identification down to the execution of sand consolidation and temporary isolation between zones are discussed. Technology is compared in terms of resin fluid system types. Laboratory testing on the core samples illustrates how the chemical consolidation process physically manifests. This is used to substantiate the field designs, execution plan, initial results, follow-up, lessons learned, and best practices used to maximize the life of a sand-free producer well. This success story illustrates potential opportunity in using sand consolidation as a primary method in the future.

Multistage Hydraulic Fracturing of the Tyumen Suite Reservoirs of Em-Yogovskoye Field: Frac-Design, Practice, Results

2021 ◽  
Author(s):  
Mikhail Ivanovich Samoilov ◽  
Vladimir Nikolaevich Astafyev ◽  
Evgeny Faritovich Musin
Keyword(s):  
Hydraulic Fracturing ◽  
Modular Design ◽  
West Siberia ◽  
Field Development ◽  
Well Completion ◽  
Multistage Hydraulic Fracturing ◽  
Sequence Of Events ◽  
Multi Stage ◽  
Development Plans ◽  
Operational Decision Making

Abstract The paper describes a system of approaches to the design and engineering support of multistage hydraulic fracturing: A method of developing multiple-option modular design of multistage hydraulic fracturing which is a tool for operational decision-making in the process of hydraulic fracturing.Building a Hydraulic Fracturing Designs Matrix when optimizing field development plans. The result was used to build decision maps for finding well completion methods and selecting a baseline hydraulic fracturing design. The paper also describes how the systematization of approaches, methodological developments, and decision templates can help in optimizing field development by drilling directional and horizontal wells followed by multi-stage hydraulic fracturing. The sequence of events and tasks that led to the development of the methodology, as well as its potential, is briefly described. The methodologies were developed during the execution of a hydraulic fracturing project at JK 29 reservoirs of the Tyumen Suite of Em-Yogovskoye field, after which they were applied in a number of other projects for the development of hard-to-recover hydrocarbon reserves in West Siberia.

Understanding Unusual Diagnostic Fracture Injection Test Results in Tight Gas Fields - A Holistic Approach to Resolving the Data

2015 ◽  
Author(s):  
R.N.. N. Naidu ◽  
E.A.. A. Guevara ◽  
A.J.. J. Twynam ◽  
J.. Rueda ◽  
W.. Dawson ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Test Procedure ◽  
Holistic Approach ◽  
In Situ Stress ◽  
Lessons Learned ◽  
Petroleum Engineering ◽  
Tight Gas ◽  
Review Team ◽  
Gas Fields ◽  
The Impact

Abstract Hydraulic fracturing is a commonly used completion approach for extracting hydrocarbon resources from formations, particularly in those formations of very low permeability. As part of this process the use of Diagnostic Fracture Injection Tests (DFIT) can provide valuable information. When the measured pressures in such tests are outside the expected range for a given formation, a number of possibilities and questions will arise. Such considerations may include: What caused such inflated pressures? What is the in-situ stress state? Was there a mechanical or operational problem? Was the test procedure or the test equipment at fault? What else can explain the abnormal behaviour? While there may not be simple answers to all of these questions, such an experience can lead to a technically inaccurate conclusion based on inadequate analysis. A recently completed project faced just such a challenge, initially resulting in poor hydraulic fracturing efficiency and a requirement to understand the root causes. In support of this, a thorough analysis involving a multi-disciplinary review team from several technical areas, including petrophysics, rock/geo-mechanics, fluids testing/engineering, completions engineering, hydraulic fracture design and petroleum engineering, was undertaken. This paper describes the evolution of this study, the work performed, the results and conclusions from the analysis. The key factors involved in planning a successful DFIT are highlighted with a general template and a work process for future testing provided. The importance of appreciating the impact of the drilling and completion fluids composition, their properties and their compatibility with the formation fluids are addressed. The overall process and technical approach from this case study in tight gas fields, will have applicability across similar fields and the lessons learned could help unlock those reserves that are initially deemed technically or even commercially unattractive due to abnormal or unexpected behaviour measured during a DFIT operation.

scholarly journals Evaluasi Stimulasi Hydraulic Fracturing Menggunakan Software Mfrac

2019 ◽  
Vol 3 (1) ◽  
pp. 30
Author(s):  
Novita Ratna Dila
Keyword(s):  
Hydraulic Fracturing ◽  
Simulation Software ◽  
Productivity Index ◽  
Service Company ◽  
Step Rate ◽  
Related Data ◽  
Well Completion ◽  
Before And After ◽  
Calculation Results ◽  
Rate Test

<p>Perekahan hidraulik (<em>hydraulic fracturing</em>) merupakan suatu usaha untuk meningkatkan produktivitas suatu sumur dengan jalan membuat saluran konduktif bagi fluida produksi untuk mengalir dari reservoir menuju sumur. Keberhasilan dari pelaksanaan perekahan hidraulik ini dapat diketahui dari beberapa parameter. Adapun parameter keberhasilan tersebut diantaranya peningkatan permeabilitas formasi, peningkatan indeks produktivitas (PI) dan peningkatan laju produksi.Tujuan dari Perekahan hidraulik akan membahas evaluasi keberhasilan setelah perekahan hidraulik dilakukan, dimana yang menjadi acuan adalah kenaikan permeabilitas dan peningkatan laju produksi.Metodologi penelitian ini, menggunakan <em>software</em> <em>M</em><em>F</em><em>rac</em> <em>Simulation</em> dari Meyer &amp; Associates, Inc. yang dimiliki oleh <em>service company</em>. Dengan memasukkan data reservoir, data lithologi batuan, data komplesi sumur, data <em>proppant,</em>data fluida perekah serta data-data lain yang terkait. Adapun tahap-tahap dari operasi stimulasi <em>hydraulic fracturing </em>ini meliputi <em>step rate test, minifrac</em>, evaluasi <em>minifrac</em>, dan <em>main fracturing</em>. Peningkatan produktivitas sumur terlihat sangat jelas dari hasil perbandingan <em>productivity index</em> (PI) sebelum dan sesudah <em>hydraulic fracturing</em>. Hasil perhitungan memperlihatkan bahwa dari hasil <em>software </em>Mfrac menunjukkan nilai PI naik 2,8126 kali lebih besar daripada PI sebelum <em>hydraulic fracturing.</em></p><p><em></em><em>Hydraulic fracturing is an attempt to increase the productivity of a well by making a conductive channel for the production fluid to flow from the reservoir to the well. The success of the implementation of hydraulic fracturing can be seen from several parameters. The success parameters include increasing formation permeability, increasing productivity index (PI) and increasing production rates. The purpose of hydraulic fracturing will be to discuss the success of the evaluation after hydraulic fracturing is done, where the reference is to increase permeability and increase the rate of production. The methodology of this research, using MFrac Simulation software from Meyer &amp; Associates, Inc. owned by a service company. By entering reservoir data, lithological data of rocks, well completion data, proppant data, recycled fluid data and other related data. The stages of hydraulic fracturing stimulation operations include step rate test, minifrac, minifrac evaluation, and playing fracturing. Increased productivity of the well is very clear from the results of the comparison of productivity index (PI) before and after hydraulic fracturing. The calculation results show that from the Mfrac software results show the PI value increases 2.8126 times greater than the PI before hydraulic fracturing.</em></p>

Pushing the Boundaries of Plug Milling in Deformed Liners – Best Practices and Lessons Learned

2021 ◽  
Author(s):  
Saad Hamid ◽  
Vikram Unnikrishnan ◽  
Abdulrahman Aljughayman
Keyword(s):  
Best Practices ◽  
Hydraulic Fracturing ◽  
Video Camera ◽  
Lessons Learned ◽  
Metal Loss ◽  
Coiled Tubing ◽  
Milling Operations ◽  
Outer Periphery ◽  
Calculated Risk ◽  
Pass Through

Abstract This paper presents a systematic workflow/methodology developed to evaluate the milling operations using coiled tubing to remove frac plugs in a well with deformed liner, post hydraulic fracturing. This paper also presents the challenges encountered during intervention and steps on how they were mitigated. The well was completed by hydraulic fracturing of five stages, each separated by a frac plug. Post stimulation, coiled tubing was mobilized to mill the plugs and provide a full bore to begin production. After spending substantial time while attempting to mill in the initial run, decision was made to POOH and inspect the BHA. It was observed that the mill had significant metal loss on the outer periphery with no damage to the mill face, which thereby concluded the presence of liner damage. A strategy was developed on how to remediate this challenge. Multiple coiled tubing diagnostic runs were performed with real-time coiled tubing capabilities, which included cleanout, camera and caliper runs. Results of each coiled tubing run performed was carefully evaluated to estimate the extent of liner damage. The caliper and video camera runs were important to determine the new reduced ID of the liner. An initial milling attempt with a 3.33" OD mill was performed, which was the smallest size based on the plug manufacturers recommendation. However due to the specific nature of liner damage it could not pass through the restriction. After further discussions, a calculated risk was taken to run with a 3.125" OD mill, which was significantly smaller than the manufacturer's recommendation, and posed an inherent threat of milling through the core of the plug, while leaving the slips intact. This however did not happen, and all four plugs were successfully milled out from the liner, allowing full bore access and well to be flowed back. This paper will act as a guideline on how to design and execute an intervention operation in deformed liners.

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