bluuebunny/crossref_metadata_2025 huggingface dataset:
Drilling with Digital Twins
Authors: Nadhan Derek , Mayani Maryam Gholami , Rommetveit Rolv
Published: October 2018

The industry is undergoing a transition into efficient technologies and it has digitalization written all over it. Digitalization not only should be about data, a fancy software, touchscreens and the internet, it is important that solutions are able to connect within existing work processes and with people for companies to truly lead to more efficient and safer drilling operations.

Oil and gas industries are now moving towards using Digital Twin's during the life-cycle of well construction. The concept of Digital Twins was first introduced by Dr. Michael Grieves at the University of Michigan in 2002 through Grieves’ Executive Course on Product Lifecycle Management. Digital Twin is a digital copy of the physical systems and act as a connection between physics and digital world. The digital system gets the real-time data from the mechanical systems which include all functionality and operational status of the physical system. An example from another industry; A Formula 1 team uses data from many sensors used in the car, harnessing data and using algorithms to make projections about what's ahead, and apply complex computer models to relay optimal race strategies back to the driver. Ultimately, to drive faster and safer.

By means of the digital twin of the drilling wells during the life cycle of the drilling by combining digital and real-time data together with predictive diagnostic messages there is seen a lot of advantageous in the improvement of accuracy in decision making and results. This again will help the industry to increase safety, improve efficiency and gain the best economic-value-based decision. A Digital Twin driven by real-time data helps to give operations the optimal plan with focus on safety, risk reduction and improved performance.

In this paper, the concept will first be explained in creating and utilizing a Digital Twin of your well for drilling and how it will directly influence how Drilling/well engineers, managers and supervisors plan, prepare and monitor their drilling operations and then implement learnings on future wells; for faster and improved decision making with direct relation to predicting and avoiding/mitigating NPT while also optimizing operations along with it. Case examples will be shared, showing value from use of the Digital Twin from first introduced in 2008 up until now where operators around the globe have implemented it for multiple uses in the drilling lifecycle.
An Experimental Study on Carbonated Water Injection of Core Samples from Tight Oil Reservoirs from Ordos Basin
Authors: Zou Jiandong , Liao Xinwei , Li Xiaoming , Zhu Zengguo , Chu Hongyang , Yuan Zhou , Luo Weiyun , Shen Xudong
Published: October 2018

Carbonated water injection (CWI) is considered to be a win-win association for enhancing oil recovery and reducing environmental footprint. Therefore, the study of CWI potential has gained tremendous attention recently. Unfortunately, the dedicated research so far focus heavily on conventional reservoirs. In order to expand the application scope of CWI, the objective of this study is to carry out a coreflooding investigation of core samples from tight oil reservoirs.

The experiments were carefully designed to assess the performance of CWI and to quantify the potential of additional oil recovery and CO2 storage capacity under various experimental conditions. We presented the results of a series of CWI coreflood experiments using the reservoir cores of tight sandstone with live crude oil. It is found that the ultimate oil recovery by CWI is higher than the conventional water injection in both secondary and tertiary recovery mode. The complex mechanisms are also investigated including CO2 content of injected carbonated water (CW), oil swelling and viscosity reduction.

It was observed that both secondary and tertiary CWI could recover a significant amount of additional oil compared to conventional water injection. The results revealed that the oil recovery would be lower if CO2 concentration is reduced, but the extent of oil recovery reduction would be much less than the level of reduction in CO2 concentration. Oil swelling as a result of CO2 diffusion into the oil raised the pressure, and the reduction of subsequent oil viscosity were amongst the main mechanisms of oil recovery by CWI, which were obtained by the high pressure coreflood models and PVT studies. Higher oil recovery was obtained with the higher permeability and higher carbonation level. At the end of the injection period, an encouraging amount of dissolved CO2 was stored in the brine and the residual oil of the tight sandstone.

The experimental results clearly indicate the potential of CWI for improving oil recovery and CO2 storage capacity in tight oil reservoirs. It is particularly attractive for the implementation of CWI for reservoirs that have limited access to large amounts of CO2. To the best of our knowledge, this is the first time to experimentally investigate CWI potential in tight oil reservoirs.
Prospects for the Spectral Noise Logging Application in the Analysis of Stimulated Reservoir Volume in Horizontal Wells with Multistage Fracturing
Authors: Nagimov Vener , Alekseev Aleksey , Tolmachev Evgeny , Maslennikova Yulia , Shigapov Ilnur
Published: October 2018

The most effective technique of low-permeability reservoir development is multistage hydraulic fracturing (hydrofrac) in horizontal wells. One of the specific features in operating such wells is that in the vast majority of cases flow rates from the created fractures are insignificant and remain below the sensitivity threshold of most tools that are part of the conventional production logging suite. In addition, development of unconventional reservoirs, such as Bazhenov formation, requires application of special hydraulic fracturing techniques. Therefore, estimation of the contribution from each frac stage into the total production and diagnostics of active fracs are essential and challenging tasks. To solve these tasks, the production logging suite that was run in a horizontal well to Bazhenov formation included Spectral Noise Logging tool which can not only locate the flow zones but is also suitable for identification of the flow zone type. This paper discusses the approaches to Spectral Nose Logging data analysis focused on the problem mentioned above and provides several case studies dealing with application of the production logging suite supplemented with SNL in a horizontal well drilled in Palyanovo area of Kranoleninsk field where multistage fracs had been carried out in the Bazhenov Deposits.
Approach to Understanding the Stimulated Reservoir Volume in Unconventional Oil Reservoirs
Authors: Dvoretskaya Ekaterina Alexandrovna , Salishchev Mikhail Vsevolodovich
Published: October 2018

At the early stage of unconventional oil field exploitation under circumstances by lack of geomechanical reservoir model the way to estimate drainage volume of fractured horizontal well is considered.

In order to create connected reservoir volume and to improve reservoir sweep efficiency though the initiating drainage channels in unconventional reservoirs multiple hydraulic fracturing is used. It improves the recovery of oil from previously impermeable vast pore volume. In this case the target of stimulation is not a planar fracture with definite length and height but the supreme rock failure directed to development induced fracturing network and therefore hydraulic techniques distinguishes from standard one. Generally this complex network is achieved by specific hydraulic fluids injection at elevated rates. As a result artificial fractured rock volume is created in the reservoir and provides the draining of a great previously unavailable hydrocarbon reserves which sustaining high production rates and acceptable cummulative oil production per well.

The concept of stimulated reservoir volume is used for the purpose of characterizing the rock volume subjected to stimulation. In the result of this treatment the complex hydraulically communicated fracture network is generated around the horizontal well. It defined by extensive improved filtration properties due to permeability of induced fractures. Initial stock tank oil in place is governed by rock capacities and saturation of mobile hydrocarbons.

Effects associated with fractures are the key ones for production intensification since they define the distribution of fluid's flow paths in the reservoir. The possibility of their accounting in the simulation modelling is an important challenge since it directly defines the history matching quality and therefore the forecast of long-term production.

During the application of the concept of stimulated reservoir (SRV) penetrating with multi-fractured horizontal well the necessity in stimulated reservoir volume characterization is arised. This characterization concerned with the base properties which exert the impact on well productivity index and on the oil recovery factor. Then as a result, the use of mathematical modeling to solve the inverse problem to clarify the structure and properties of unconventional formation by reproducing the history of development authors state three basic geological and technological parameters which define the well production performance of unconventional reservoir with SRV – the volume of stimulated zone, shape-factor and effective permeability of fractured zone.

At the early stage of exploitation the unconventional reservoir, which characterized by the availability of production history and the drawback of geomechanical data, the approach is presented which provides an opportunity to create the fluid-flow reservoir model ensures with higher degree of accuracy and more reliable long-term production forecast.
On the Mechanisms of the Formation of Zones with Abnormally High Rock Pressure and Methods for Predicting them in Undeveloped Rock Systems
Authors: Islamov Azamat , Kolupaev Dmitriy , Faskhutdinov Ruslan , Vereschagin Sergei
Published: October 2018

To the list of the most serious and uncontrolled geological complications arising during the drilling of wells, it is well known the Oil, Gas and Water Shows (OGWS) which often happens in areas with formed waterflooding zones. Risks result from the lack of the ability to predict the location of Abnormally High Reservoir Pressures zones (AHRPZ) due to high uncertainties in the movement of the injected fluid in formation.

Oversight of the meeting of reservoir zones with high reservoir pressure is conducted on the basis of a number of analytical tasks: making water-oil factor maps, ping the front of the injection water in formation, pressure (isobar) maps, drilling history, special field geophysical tests for formation cross-flows, CO-logs across not perforated productive intervals.

However, by using the classical development tools, it is possible to solve the issues with predicting the potential high pressure zones in the flooded reservoirs, but how we can predict the abnormal pressure systems in reservoirs that are not under development and carry exclusively technogenic genesis?! In this paper we will talk about the forecasting possibility of the abnormal pressures in the transit reservoir systems using the example of the Priobskoye oilfield. Those systems are not involved in the development process either because of the lack of hydrocarbon reserves or because of the absence of the reservoir at all. The authors hope that this materials allow to describe the tools that will protect other colleagues from complications related with well drilling and their re-drilling with associated material costs.
The First Experience of Formate Based Drilling Fluids Application in Russia
Authors: Ryabtsev Peter Leonidovich , Khomutov Anton Yuryevich , Korolev Andrey Vladimirovich
Published: October 2018

Notwithstanding significant advantages of the oil-base mud systems, their application inherent in a number of disadvantages that have been primarily attributable to environmental restrictions. In 2017 AKROS LLC and GAZPROMNEFT ran full-scale field-testing of potassium and sodium formate mud systems enabling them to analyze the performance of such systems and define the key application features. Conclusions on the application features of these systems and their perspectives in Russia are based on the results of the work performed.

To implement potassium and sodium formate drilling fluids in GAZPROMNEFT fields, the full-scale laboratory testing was performed. The outcomes enabled the identification of fluid formulations for field applications and procedures for the maintainance of mud properties when drilling.

Two intervals on «Gazpromneft-Khantos»' LLCs Yuzhno-Priobskoye Field and three intervals on

«Gazprom Neft Shelf» LLC's Prirazlomnoye Field were drilled with potassium formate-base formulations.

Field testing proved the high efficiency of potassium formate mud systems allowing them to: –achieve high drilling performance indicators;–gain experience in horizontal well drilling without lubricating additives demonstrating loads and torques similar to or lower than values observed in mud systems treated with lubricants;–develop the procedure for interval treatment of a high-density drilling fluid;–confirm the possibility of achieving a high density up to 1.41 g/cm3 without barite;–implement the technology ensuring mitigation of environmental risks connected with drilling fluids;–drill horizontal section and production casing intervals using one type of drilling fluid instead of two, facilitating reduced waste and prepared volumes.

The potassium formate mud system proved to be efficient and has impressive perspectives in Russia as an alternative to oil-base drilling fluids, particularly for high formation pressure drilling. Based on field application results, practical application procedures and optimum recommendations for controlling mud properties were developed. Comparative tests for inhibition effectiveness, reducing friction factor, achieving high drilling performance were conducted.
Design and Process Engineering of Slotted Liner Running in Extended Reach Drilling Wells
Authors: Kunshin Andrey , Dvoynikov Mikhail
Published: October 2018

In this paper, the process of developing an improved design of slotted liner, which makes it possible to increase the efficiency of running into extended-reach wells is considered. The options of running a liner with the filter through the power sub or swivel are discussed. Each option of running is estimated and the optimal method is selected. A scenario is proposed with changing the filter part of the assembly to optimize the strength and dynamic characteristics during well completion and subsequent field operation. Existing models of filters are considered, their shortcomings are discovered and, on this basis, a digital filter prototype is proposed.

A filter assembly with guiding turbulators, their number and arrangement are proposed. The prototype is designed and printed on a 3D-printer.

The calculations result of the friction moment during its running are presented. The criteria for installing guiding turbulators on a filter are established, which prevents the filter body to deflect from its own weight and contact with the borehole wall.

Technical and economic indicators are calculated, which show the attractivity of the project in several criteria (blocks).
The Combination of Ridge and Conical Elements is a New Approach for Drilling Out Hard Carbonates and Sandstones Without Drop in ROP
Authors: Lomov Alexander , James Biju , Konysbekuly Galymzhan , Gumich Dmitrii , Rasulov Ruslan
Published: October 2018

Designing and developing competitive tools for use in the oil and gas industry to meet the high-demand market requires years of experience and a high-level knowledge base. In today’s drilling environment, innovations in bit technologies play an increasingly important role to improve overall drilling performance and reduce drilling time. Cylindrical cutters had their own limitations and restricted the drilling industry from advancing the operations performance to the next level. 3D-shaped cutters were developed to provide maximum drilling efficiency in the most challenging applications by mitigating cutting structure damage and improving its technical limits. The invention of the 3D polycrystalline diamond cutter (PDC) is helping operators to drill wells faster by improving rate of penetration (ROP) and reducing in-out trips.

The combination of ridged diamond element (RDE) and conical diamond element (CDE) on bits is a new method for drilling formations. These bits improve drilling ROP by maximizing the shape of the PDC cutters. This combination also improves cutter durability, which in turn, enhances bit performance and drilling efficiency. Bits equipped with these 3D cutters require less mechanical specific energy during drilling compared with bits having conventional cylindrical cutters, which helps to reduce shock and vibrations and weight on bit required to drill hard formations.

Field data have proved, beyond any doubt, the benefits from using the combination of 3D PDC cutters in drilling hard formations. These cutters, depending on the shape, are able to improve ROP and durability, and by placing them in the right position on the bit, can improve the overall durability of the bit.

Multiple field tests were conducted in various applications with customers in Russia. The results clearly showed that the combination of these unique 3D cutters helped operators achieve a step change in performance by improving ROP and depth drilled. In some cases, operators were able to drill an entire section using bits equipped with 3D cutter combinations, whereas traditionally more than one bit was used to complete the section. This paper will present the advantages provided by 3D cutters and by implementing a combination of CDE and RDE 3D elements in challenging applications in Russia, in addition to performance benchmarks achieved using this unique combination of 3D cutter combinations.
Integrated Approach to Real-Time Drilling Optimization Based on Methods of Geosteering, Petrophysics and Geomechanics
Authors: Mylnikov Danila , Tatur Olga , Sabirov Airat , Brazlauskas Anton , Petrakov Uriy , Sobolev Alexey , Sigarev Sergei , Kustarev Dmitry , Yakovlev Konstantin
Published: October 2018

The objective of this work was to drill a horizontal well in the Bazhen formation (Western Siberia, Severo-Demyanskoye field) in order to achieve the maximum possible efficiency both from technological and economical points of view. To solve the task, it was decided to apply a integrated approach to drilling support: synchronously use the methods of geosteering, the results of geomechanical modeling and evaluation of the reservoir properties during the drilling process. The experience of drilling support accumulated by the company at the beginning of the work demonstrated that the coordinated use of the three disciplines leads to an increase in the efficiency of the well construction process.

Pre-drill geomechanical models of the geological interval of interest were constructed for the target well, and also reservoir properties were evaluated. The wellbore stability analysis is carried out and intervals with high risks of destruction of a breed on walls of a chink are revealed. To minimize risks, recommendations were given on the technological parameters of the well construction: mud weight, casing shoe depth, etc.

Based on the actually measured rock properties, the petrophysical characteristics of the formation were evaluated. Geosteering methods were used to correct the trajectory in real time for the most efficient well placement in the target interval with the best reservoir properties. Every time the trajectory was changed, the geomechanical model was rebuilt, demonstrating an updated risk map. As a result, the well trajectory was adjusted taking into account minimization of unstable borehole risks.
Multiphase Flow Metering-A Case Study from Badra Oil Field
Authors: Hosgor Fatma Bahar , Toral Haluk , Cai Shiqian , Dudich Maksim , Ilyassov Arman , Budarin Gennadiy , Malyavko Alexander
Published: October 2018

This paper presents the full cycle project experience for the implementation of multiphase flow meters at the Badra Oil field at the well head and production lines, including a discussion of the design and selection criteria and a detailed description of flow loop proving, commissioning and on-going validation and tune up procedures. In addition, results of further research based on field data is presented including a study of the potential of neural nets for transfer learning and automated malfunction detection.
Completion Design Optimization for Production Wells on Badra Oilfield
Authors: Kuzovkin Ilia
Published: October 2018

Badra oilfield started production in 2014.

After some time from the beginning of the field operation, several troubles manifested itself.

Analysis of tubing performance detected clear indication of gas slippage effect on low rate wells and tubing choking effect on high rate wells. Several issues with well integrity also lead to re-assessment of completion design.

During selection of new tubing size and completion equipment, factors like production rate, reservoir depletion, GOR, Flowing buttonhole pressure, wellhead pressure and temperature were taken into account.

In addition to that, possible well interventions and expected tubing loads were considered.

As a result three groups of wells have been identified - low, high and medium production rates in terms of Badra field with new completion concept for each group.

New completion design was selected and implemented on several wells and showed its better performance for new production conditions.

Moreover, selected production tubing diameter and completion components has lower cost and allows any well interventions that might be planned on the field. In addition to that, new completion string can last longer due to its higher corrosion allowance.
Application of the Evolutionary Algorithm for Creating Advanced Technologies for the Beneficial Use of Gas in Order to Increase the Efficiency and Reliability of the Operation of the Technological Equipment
Authors: Vlasov Artem , Fedorenko Valery , Yakovlev Vitaly
Published: October 2018

The work is devoted to the estimation of the contribution of the achievements of science and technology realized in the technological equipment for the use of gas aimed at increasing the reliability and efficiency of solutions for field development.

Increasing the efficiency and reliability of gas utilization systems is possible through the integration of technological solutions based on combined physical effects into their composition. Integration into old or newly created equipment of scientific and technical discoveries allows creating flexible technological solutions. Reducing the mass-dimensional characteristics of equipment for the use of gas is achieved through the use of modern lightweight materials and structures, and the integration of equipment into single block-modular construction-variable structures. The design of the building-alterable elements of new products in full factory readiness reduces the construction and installation costs by 10-15%, allows to reduce the occupied area of installations by 5 times

The evolutionary algorithm for creating advanced technologies for the useful use of gas is based on the integration of scientific and technological discoveries into old or newly created equipment.

The solutions developed by the algorithm include the latest achievements of science and technology. Such solutions for gas utilization systems allow: to reduce costs for CAPEX and OPEX up to 5-10%, increase efficiency of electric installation drive (~ 10%), reduce oil carryover with gas up to 3-5%, return additional volume of liquid hydrocarbons (110- 150 g / m3) into commercial oil.
Criteria of Gas and Gas-Condensate Wells Production Co-Processing Using a Single Processing Train at the Gas Processing Plant
Authors: Nerodenko Dmitriy , Kudrin Pavel
Published: October 2018

A new approach is proposed to choose the option for gathering and processing of hydrocarbons in the commingled development of natural gas fields with a low potential content of C3+ hydrocarbons (for this article purpose, they are hydrocarbons of Aptian-Albian-Cenomanian deposits with a potential content of C3+ hydrocarbons up to 3 g/m3) (hereinafter dry gas) and natural gas with a high content of C3+ hydrocarbons (for this article purpose, it means hydrocarbons of Neocomian, Achimov and Jurassic deposits with a potential content of C3+ hydrocarbons of more than 100 g/m3) (hereinafter wet gas).

The option for commingled gathering and processing of hydrocarbons using shared process facilities by the method of a low temperature separation (LTS) is under consideration as well as the option for the separate arrangement for hydrocarbons with a different content of condensate.

The approach novelty is to use available calculation results for basic criteria that determine technical and economic efficiency of choosing a particular option for gathering and processing of hydrocarbons.

The option choice for hydrocarbon processing is determined by economic efficiency, which in turn depends on the amount of condensate losses with sales gas in the option for commingled gathering and processing of hydrocarbons. The loss of condensate is meant the volume of C3+ hydrocarbons converted to a gaseous state in the process of hydrocarbons processing as a result of mixing of dry and wet gases. In this paper, the relationship of condensate losses with sales gas when changing different criteria affecting its amount is established and illustrated.

The road map to select the option for gathering and processing of hydrocarbons is developed and presented in the form of successive calculations and analytical stages that allow researchers to quickly analyze each particular development option and take a decision on the choice of the most profitable option for processing of dry gas or reject a knowingly loss-making option.

The application of this approach will enable to significantly reduce time losses at "Assessment" and "Choice" stages and not to require services of highly qualified personnel for material balance calculations of the process facility.
Determination of Operating Efficiency of Sucker-Rod Pumping Units of Different Design in Horizontal Wells
Authors: Kitapov Ildar , Gilfanov Rustam
Published: October 2018

The objective of this study was to develop a sucker-rod pumping unit with a special design and to test it in the given conditions. Such conditions are the wells with a horizontal well bore or controlled directional sidetrack, operated with sucker-rod pumping units within the bore curvature ranges close to 90°.

The tasks of this development were the following: operation of horizontal wells with the maximum bottom hole pressure reduction; increase in the drainage speed; increase in the volume efficiency of the sucker-rod pumping units when operated in horizontal wells in fields in their later stage of development; decrease in the impact of gas on sucker-rod pumping unit operating efficiency.

Complications in operation of wells with horizontal well bores or controlled directional sidetracks are following: restricted use of different types of pumps in lifting operations; the main type is operation of sucker-rod pumping units in the curvature ranges that do not exceed 42°. If exceeded, this value leads to reduction of pump fillage by 14% [1] or complete pump starvation due to the valve operating with delay when the valve settles into its seat, which leads to leakages through valve foam.
Study of the Submersible Sand Separator in the Field of Centrifugal Forces for Increasing the Artificial Lift Efficiency
Authors: Nikonov Evgeny , Goridko Kirill , Verbitsky Vladimir
Published: October 2018

High mechanical impurities content in production fluid is one of the main causes high mechanical impurities content in production fluid. In the field practice there are many technologies to minimize solid phase flow from reservoir to the bottomhole and various technique units to protect submersible pumping equipment. However, currently there is no detailed study of technical and technological efficiency parameters.

Different methods and technologies to solve the problems of oil (water) well production, complicated by solid phase flow, are used. In this paper the study results of the submersible sand centrifugal separation for artificial lift are presented, with consideration of the abnormal well conditions.

In Gubkin University at Reservoir and Production Petroleum Engineering Department (RPPED) experimental stand unit to complex study of submersible sand separator (model “PSM") with hydraulic gate was constructed. Experimental stand unit allows determining submersible sand separator (SSS) efficiency. The submersible sand separator experimental stand studies have been conducted on model mixtures “water – solid particles (suspended solids content up to below 2 g/l)" and “water – gas (flow gas content up to 60%) – solid particles". The influence patterns of suspended solids content, inlet flow gas content and granulometric on “PSM" separation efficiency are determined.

The “PSM" efficiency was experimentally confirmed and the separation coefficient values were obtained, which exceeded the performance of the similar devices. The workflow to select candidate-wells for this protective device application was developed. A new technological scheme to lift separated impurities bypassing submersible pumping equipment on the day surface is proposed.
Phase Transitions in the Preparation of Oil Extracted from Oil Rims
Authors: Ivanov Sergei
Published: October 2018

Most of the undeveloped reserves in Russia are hard to recover (TRIZ) and are poorly understood (over 65% of undeveloped reserves are classified as C2 reserves) [1]. Hard-to-recover reserves (TRIZ) – reserves of deposits (fields, objects of development) or parts of the Deposit, characterized by relatively unfavorable geological conditions for the extraction of oil and (or) its physical properties, the development of which by existing technologies in the current tax system is economically inefficient [2].

Hard-to-recover reserves include: Deposits with high-viscosity oils;Depleted (depleted) deposits;Thin oil rims;Deposits which are remote from the infrastructure;Deposits with low-permeability reservoirs;Unconventional reserves: Bazhenov, Abalak, Hadum and domanik formation;Gas hydrate deposits.

The main feature of the oil rims is a small reservoir capacity: from 2-3 to 15 m above the oil layer located a much bigger gas cap, which is in a hydrodynamic connection with the oil. The development of these deposits is due to the following characteristics: –full hydrodynamic connection of the oil layer with the gas cap and the aquifer and mobility of oil and gas and water contacts in the development of the Deposit;–uniform distribution of reservoir energy over the oil and gas area, equal to the initial reservoir pressure and oil saturation pressure;–relatively close location to the faces of oil and gas wells and water-oil contacts in the drainage of oil rims;–instability of the process of oil displacement by gas, leading to a rapid gas breakthrough to the bottoms of production wells, increase of the gas factor of the produced fluid and ultimately to a significant loss of reservoir energy and a decrease in oil recovery;–the possibility of retrograde condensation due to the pressure reduction in the gas-saturated zone of the formation, which predetermines the formation losses of condensate;–maintaining reservoir pressure (PPD) is ineffective and is not able to keep the gas cap in its original position.

As a result, oil recovery does not exceed 10% of the initial reserves [3].
A Case Study of an Efficient and Cost-Saving ICD Completion Design to Manage Production Flow Heterogeneity in Filanovskogo Russia Field
Authors: Osunjaye Gbenga , Abdelfattah Tarik , Snitkoff Joshua , Absalyamov Roman , Golenkin Mikhail , Zavyalov Alexander , Stolboushkin Eugene , Rymarenko Konstantin , Nukhaev Marat
Published: October 2018

Typical wells in the Filanovskogo field are in a multi-zone reservoir with heterogeneous production flow profiles. The use of inflow control devices (ICD) in conjunction with zonal isolation packers, though successful, continues to evolve to improve overall ICD performance. However, in a contemporary cost-driven oil and gas market, persistent innovation has resulted in ICD performance improvement, and it has introduced changes that yield cost-effective deployment approaches, as evident in this case for Filanovskogo field.

This paper details the inherent production challenges posed by the heterogeneity of Filanovskogo reservoir flow profiles. Analysis of the flow profiles facilitated an optimal inflow control modeling that efficiently balanced the production inflow across the various zones and provided means to restrict water inflow selectively. The ICD modeling yielded a solution that assured an improvement in oil recovery from the reservoir. In addition to the sought-after production benefit, the completion design incorporated equipment that collectively reduced operation sequence.

The executed completion design features installation of nozzle-type ICDs fitted with premium screens and integral screen isolation valves. An in-depth look into the operational steps is provided, along with a comprehensive review of the technologies that facilitated this streamlined execution. This review includes a technical overview of the integral sliding choke sleeve of the ICD that can be actuated open/close in the future to manage water ingress. The outcome of this completion design is a solution that saves wellsite operating hours, allows execution of multiple steps simultaneously, depicts production flow balance, and ultimately delivers an enhanced oil production lifespan.

This completion design has leveraged the successes from industry best practices, particularly in ICD applications, to devise a region-specific solution that is relevant in today's cash-conservative market.
Standalone Sand Control Failure: Review of Slotted Liner, Wire Wrap Screen, and Premium Mesh Screen Failure Mechanism
Authors: Mahmoudi Mahdi , Roostaei Morteza , Fattahpour Vahidoddin , Sutton Colby , Fermaniuk Brent , Zhu Da , Jung Heeseok , Li Jiankuan , Sun Chong , Gong Lu , Shuang Shuo , Qiu Xiaoyong , Zeng Hongbo , Luo Jing-Li
Published: October 2018

Standalone screen has been widely used as sand control solution in oil industries for over a century. Screen plugging and impairments by formation fines, scaling and corrosion cost oil and gas industry significant amount of resources. This study presents a detailed study on the corrosion and plugging of slotted liner, wire wrap screen and mesh screen samples extracted from the field to better understand some of the mechanisms for these poor field performances.

Three types of standalone screen were received from operating wells to study the failure mechanism of the screen and provide recommendations for recompletion. A thorough visual inspection of all screens was performed and documented in this paper. From the results of the visual inspection a certain section of each screen was cut for further detailed microscopic study to better understand the scaling and plugging mechanism, as well as microscopic geometry of the plugged and corroded zone.

The results highlighted the importance of the corrosion in the base pipe on the observed performances. All the studies pointed toward the flow dependence corrosion behavior, and the role of the water cut on the corrosion rate. The wire wrap screens have been in service for less than a year, yet the extensive corrosion led to creation of several holes in the pipe. The study showed the corrosion initiated from inside the pipe. Similarly, the corrosion of the slotted liner samples showed a strong flow dependent corrosion rate, where the corrosion rate on the slot/formation interface was slightly higher. The mesh screen showed very high plugging percentage by formation fines, where a thick film of clay and fine sand covered the space between the mesh and the base pipe. The results indicated that an inappropriate design of the mesh and pore could cause significant plugging.

This paper provides several field examples of the corrosion and plugging of the standalone screens. The results could help engineer to better understand the risk of corrosion and plugging on the standalone screen design. This paper provides some general guidelines for assessing the scaling and corrosion potential at field condition based on the results of the screens studied in the paper.
Rigless Pre-Workover Diagnostic of a Dual String Completion
Authors: Safar Emad , Al-Khatrash Mouzah , Al-Hazeem Fatema , Prosvirkin Sergey , Karantharath Radhakrishnan , Najdi Ahmad , Al-Shatti Mohammad
Published: October 2018

One of the advantages of having a dual string completion is the option to develop and produce more than one reservoir simultaneously, whereas there are considerable disadvantages too and one of such is managing the integrity of the two strings intact throughout the life time of the well. In this paper, a case study from Ahmadi Field is presented highlighting the need for effective surveillance methods to identify issues with dual string completion and successful implementation of workover.

Spectral Leak Detection (SPEC-LD) along with High Precision Temperature (HPT) tool was used to pin point the exact leak locations in the tubing strings prior to attempting the workover. Spectral Noise Tool is a passive tool with a high sensitivity hydrophone designed to record sound in the frequency range of 8 HZ to 60 KHZ. Analysis of noises recorded in various frequency ranges allows the location of flow-related features, such as wellbore flows, casing and tubing leaks, perforations, cement channelling and flows through the rock matrix and fractures. The SPEC-LD combined with a high-precision temperature (HPT) tool was found highly effective in pinpointing leak sources and quantifying it.

Ahmadi Field is one of the prolific oil fields in South Kuwait and has many dual string completions. In this paper, a case study is presented where the SPEC-LD tool was effectively deployed to identify leaks in a dual string completion. The leak and communication between the strings resulted in higher water cut from the short string which was producing at zero water cut. Based on the logging results, the well was successfully worked over in a cost-effective manner to improve the production. The workover also resulted in reducing the water production from the well, thus saving water treatment cost prior to disposal. Knowledge of the tubing condition prior to deploying the workover rig was found useful and effective in selecting the proper workover procedure, tools and techniques.

Blindly doing workover without knowing the tubing condition and well integrity generally results in the application of wrong workover processes and techniques causing overspending and safety concerns. Evaluating the condition of the tubing string and pinpointing the leaks was found useful in planning proper workover and thus minimizing the cost as well as bringing the wells back on line on minimum time. The main message from this paper is the benefit of using appropriate evaluation techniques prior to attempting any workover to save both time and money.
Peculiarities of White Tiger Field Basement Development Forecasting: Chsllenges and Solutions
Authors: Lubnin Alexandr , Afanasiev Igor , Yudin Evgeniy , Sansiev Georgiy , Galimova Anastasia
Published: October 2018

This paper presents a method for the basement development parameters forecasting for the main offshore production object of White Tiger field. Due to peculiarities of the basement geological structure and its development the conventional approaches to the production planning for this object have low forecasting ability. The authors have developed a relevant method to solve the issue of accurate basement development parameters forecasting. A model of the well's operation process was developed on the basis of the method of the pipe multi-phase flow parameters hydraulic calculations with account of correlational PVT-functions for water, oil and gas for the purpose of describing the downhole equipment. The material balance and displacement models were used to describe the reservoir development. As a result of unification of the implemented approaches to the reservoir development and well description a method which allows significantly improving the forecasting abilities of the calculations was obtained.
Building of Effective Control and Management System for Injection Horizontal Wells During Waterflooding
Authors: Galeev Rail , Rybakov Roman , Yakovlev Andrey , Kayeshkov Ilya , Simakov Sergey , Fayzullin Ildar , Sagirov Aleksandr , Feoktistov Roman , Suleymanov Ayyar
Published: October 2018

The main uncertainties in the field development with the use of multiple-fractured horizontal wells (MFHW) in waterflooding are the inflow/injection profile along the horizontal wellbore, the number of working hydraulic fracturing ports, the dynamics of the productivity factor, the presence of the self-induced fracturing effect. All these factors affect the sweep efficiency and oil recovery factor. To remove uncertainties and increase the efficiency of waterflooding, a systematic approach to the control and management of the MFHW is required.

Implementation of this approach is an important direction of technological development of Gazprom Neft PJSC. The creation of a system for monitoring and managing the MFHW is based on the search, sampling, analysis of efficiency and selection of control technologies (geophysical studies for removal of uncertainties) and management technologies (well interventions for improvement of operational efficiency of MFHW).

One of the most promising technologies for monitoring the MFHW is long-term monitoring of downhole parameters (temperature and noise) with fiber-optic systems (FOS). Gazprom Neft PJSC has a positive expirience in this area, which includes the use of the FOS of various configurations, design and interpretation of the results of this type of research. Therefore, the main issue of using FOS in MFHW is the delivery of optical fiber to the horizontal part of the well with the possibility of further carrying out the well interventions without dismantling the FOS. The paper describes the results of testing a unique method of delivery of fiber-optic cable in the MFHW using coiled tubing and hydraulic anchor at the field in the Orenburg region.
Implementation of an Integrated Approach to Develop Low-Productivity Reservoirs of the Priobskoye Field
Authors: Shurunov Andrey , Iakovlev Andrey , Sheremeev Alexander , Kaeshkov Ilya , Rastegaeva Elena , Suleymanov Ayar , Fayzullin Ildar , Kolupaev Dmitry
Published: October 2018

Horizontal multi-fractured wells nowadays are the most common way of low-permeability reservoirs exploitation either in Russian and foreign oilfields. Besides its high efficiency such completion has a lot of factors (usually undefined) which can together significantly decrease oil rate. Here some of them are listed: Drilled horizontal well length and producing well lengthNumber of created and producing fracturesFracture length by design and by the actual production and well-testFracture location in relation to well (azimuth and initialization interval).Interference between neighborhood wells through the fractures during injection and productionEtc.

The paper deals with most interesting parts of a complex project which purpose is to realize the multi-fractured well potential and production system diagnostics. There are three main issues in this paper:

Designing – filed-sector choosing, optimum spacing and well completion calculations

Realization – well construction and studies conduction

Analysis – comparison between new project wells and common wells in the neighborhood, geological and hydrodynamic model correction

Current primary project result is a significant exploitation system efficiency growth after a change of well and fracture directions (perpendicular to the wellbore). The secondary but anyway very important results are learned lessons and new competences in well construction and studies.
The Method of Express Estimation of Pore Pressure Map Distribution in Reservoirs with Faults and Wedging Zones
Authors: Yudin Evgeniy Viktorovich , Gubanova Anna Evgen'yevna , Krasnov Vitaliy Aleksandrovich
Published: October 2018

The analysis of the energy status of a reservoir having many faults and wedging zones is a significantly complex problem which has no engineering solutions at the moment. The presented paper is aimed at developing a convenient and quickly solving engineering tool to make an isobar map for the reservoirs where large numbers of faults and reservoir fringes are present.

For the purpose of the isobar map drawing a pressure distribution equation for the porous media is solved at every time step. The boundary element method was used as a mathematical basis. This method allows accounting for all types of the reservoir structure irregularities, including faults and wedging zones. The calculation using the boundary element approach is quite fast compared to the finite element method and the finite difference method because it decreases a dimension of the problem by one. The considered engineering instrument was implemented as a separate application using C++ coding language. The monthly well data, in particular bottom-hole pressures and flow rates, are used as initial information.

Standard engineering tools such as material balance fail to fulfill the problem of the isobar map construction for the reservoirs with large numbers of faults. This is due to the fact that the material balance method does not account for dimensional distribution of areas having significant influence on the filtration flows distribution (faults, wedging zones). Use of full-scale 3D hydrodynamic models is complicated by the uncertainty of location and conductivity of faults. This factor significantly decreases the viability of using of full-scale hydrodynamic models for quick engineering calculations in course of the formation energy status analysis. The purpose of this work is in establishing a convenient algorithm which would allow assessing the reservoir energy status with account of its structural uncertainties, including presence of faults and wedging zones, with engineering accuracy using minimum volume of field information. The paper describes the main approach to the development of a reliable and quick-calculation algorithm for constructing isobar maps with account of main reservoir structure uncertainties. The accuracy verification of the obtained map against the analytical solutions and the numerical modelling results from the commercial simulators was conducted.

The calculation speed allows solving operational production tasks, including faults conductivity assessment, pressure maintenance efficiency, aquifer activity identification, well interference degree determination. Application of the program is demonstrated on the examples of the terrigenous field offshore of Vietnam and carbonate field of Timano-Pechora oil and gas province. The proposed program also allows conducting the permeability assessment for the wells and tracking the skin-factor dynamics by means of comparative analysis of well data for various dates.