Meetings

Drilling groups and executives generally have a different view of measuring drilling performance. To executives, “Drilling” commonly refers to all aspects of well construction, including drilling, completions, hook-up, procurement, the asset team, and other groups. Good measures of performance can drive improvements between these groups. The first key to success is how to communicate drilling performance in terms that answer the questions of executives and managers, which requires a business-focused cross-functional process. The second key to success is to drive operational performance improvement, which requires a different set of measures with sufficient granularity to define actions. Over the past 10 years, a very workable system has evolved through various approaches used in drilling more than 16,000 wells in the US, South America, and the Middle East. The system has delivered best-in-class performance. It has proven that an effective performance measurement system which addresses both executive requirements and operational requirements can both deliver outstanding results, and also communicate those results, with remarkable value to the organization.  

Author:

John Willis is New Mexico Drilling and Completions Manager for Occidental Oil & Gas Corporation. His responsibilities include all aspects of drilling, fracturing, and completing unconvetional horizonal wells. Prior to this role, he was Chief of Drilling, with responsibility for standards, operational support, global systems, the drilling data system, and tools for drilling performance measurement. Prior to his Chief role, he served as Drilling Manager in Oman and Drilling Manager in Libya. His experience prior to Oxy includes other drilling roles, service company roles related to project management and software development, and he operated a consulting and software business. He has Chaired two SPE Forums, served on Forum Steering Committees, and Chaired the 2003 SPE/IADC Drilling Conference.

Mathematical modeling of phase behavior of multicomponent hydrocarbon mixtures is an essential part of up-to-date practices in petroleum reservoir engineering. Phase behavior calculations form the basis of the PVT software, as well as the 'flash' procedures for determination of phase state and compositions within compositional flow simulators. Adequate description of phase behavior is important for simulation of petroleum production with intensive phase transitions in the reservoir, wells and surface facilities.

One of the key assumptions of industry adopted models is that phase state of the hydrocarbon mixture and phase compositions correspond to the condition of thermodynamic equilibrium. However, there are typical cases for oil and gas-condensate reservoirs when field data are principally inconsistent with equilibrium models. Some examples to give are data of well operation at Novogodneye, Vuktylskoye, Krasnoleninskoye, Kamennoye and many other fields.

In hydrocarbon production, non-equilibrium effects are evident in the following cases:

1) pressure increase in a reservoir (by water or gas injection) following previous pressure depletion with evaluation of the second hydrocarbon phase (liberation of dissolved gas from oil or retrograde condensation in a gas-condensate system) – so-called gas dissolution / condensate evaporation hysteresis;

2) pressure depletion in a gas-condensate reservoir below the maximum condensation pressure (transition from retrograde condensation to direct re-vaporization);

3) gas injection in oil or gas-condensate reservoir.

Similar processes may also take place during hydrocarbon flow in wellbores and surface facilities.

Non-equilibrium effects result in considerable (tens or hundreds percent) deviation of actual reservoir system parameters (saturation pressure, production composition) from their estimates by equilibrium models.

For practical needs, reservoir engineers are limited to either using equilibrium compositional models with no account for non-equilibrium effects, or black oil models with the option of limited gas dissolution /condensate vaporization/ This option is based on a simple technical relation and doesn't consider specific physics of non-equilibrium processes.

In the presentation, methods and algorithms are presented for non-equilibrium phase behavior simulations suitable for wide practical use. A relation is shown between non-equilibrium effects and simulation scale. As the applications, flow simulations with compositional and black oil formulations are considered. Phase behavior simulation cases are shown for real oil and gas-condensate mixtures, including matching of the non-equilibrium condensate recovery dynamics for the late stage of production at the Vuktylskoye field.

Author:

Ilya M. Indrupskiy

Chief researcher / head of Gas-, Oil- and Condensate Recovery Lab of the Oil and Gas Research Institute of the Russian Academy of Sciences (OGRI RAS). Professor of the Applied Mathematics and Computer Modeling Department of the Gubkin State University of Oil and Gas.

Graduated from the Gubkin University with an engineering degree in applied mathematics. Doctor of technical sciences in reservoir engineering. Professor of the Russian Academy of Sciences. Author of more than 150 journal and conference papers and more than 20 patents.

Research area includes improvement of integrated 3D reservoir modeling; forward and inverse problems of fluid flow and thermodynamics in oil and gas reservoirs; development of highly informative well testing and data interpretation methods; advancements in production techniques for hard-to-recover hydrocarbons.

Ilya has a considerable experience in research projects for the Russian Academy of Sciences, as well as for Gazprom Neft, TNK-BP, Rosneft, Lukoil, Gazprom and other companies.

Reliable information about reservoir properties and its variation within the reservoir is a key factor in reducing uncertainty within the choice of an asset development strategy, technological solutions, estimation of recoverable reserves and feasibility of development strategies. In case of waterflood designing or other methods of pressure maintenance for inhomogeneous, anisotropic collector, among necessary initial parameters we need the most accurate data on displacement efficiency, relative phase permeability functions, permeability values ​​along lateral and vertical coordinates, and principal directions of permeability tensor for complex carbonate objects. All those characteristics are currently determined from data of laboratory core studies, with total impossibility to transfer it correctly to the scale and conditions of fluid flow in formation during field development.

For 15 years the authors have been developing new methods and technologies for complex well testing. For each type of research, a specially planned sequence of technological operations, extended complex of hydrodynamic, geophysical measurements and methods production logging provide highly informative data on multidimensional multiphase filtration processes directly at reservoir conditions.

To determine desired reservoir characteristics, obtained data are interpreted by data assimilation within inverse problem solution. Corresponding forward problems are solved in transient, multiphase and / or multidimensional statement, with full consideration for object peculiarities (heterogeneity and anisotropy of formation properties, compressibility of fluids and rocks, possibility of separating dissolved gas, variable mineralization of water, etc.). Solution of corresponding inverse problems is carried out using effective optimization methods and methods of optimal control theory (adjoint method). Algorithms and software have been developed for numerical solution of forward and inverse problems.

A series of patents has been obtained for new methods of well testing and related technical solutions. Technologies are tested on a number of domestic deposits. Substantial results are obtained, new interesting effects are revealed.

Our presentation will highlight the main ideas, achieved results and accumulated experience, with an emphasis on the scientific component of topic considered.

 

S.N. Zakirov, E.S. Zakirov, I.M. Indrupsky, 
D.P. Anikeev, T.N. Tsagan-Mandjiev, M.N. Baganova, OGRI RAS

Author:

Ernest S. Zakirov

 

Professional Characteristic

Doctor of Technical Sciences, Professor of the Russian Academy of Sciences E.S. Zakirov is a leading scientist in the field of modeling oil and gas fields development, development optimization of natural hydrocarbon deposits, history matching of 3D hydrodynamic models, specialized well testing, and an expert in domestic oil and gas projects.

E.S. Zakirov already has published over 225 scientific works, including 7 monographs and 1 book, possesses more than 40 patents for inventions, including international (USA). Prepared 5 candidates of sciences. He is also SPE member.

 

Education

In 1991 he graduated cum laude from Moscow State University named after M.V. Lomonosov.

In 1991-1994 years – post-graduate student of Moscow State University named after M.V. Lomonosov.

In 1997 he defended his candidate degree.

In 2001 he defended his doctoral dissertation.

In 2015, he was elected professor of the Russian Academy of Sciences by the Department of Earth Sciences of the Russian Academy of Sciences.

 

Professional activity

1994 to present time

Principal Researcher of the Gas-Oil-Condensate Recovery Laboratory of Oil and Gas Research Institute of Russian Academy of Sciences.

Creates new and improves existing technologies for oil and gas fields development.

Along with fundamental research, he is engaged in designing and improving development of oil and gas fields, including Yaro-Yakhinskoye, Western Siberia (1997), Severo-Vasyuganskoye, Tomsk Region (1998), Talinskoe field, Western Siberia (2000), Pribrezhnoye field (2001), Prirazlomnoye, the Barents Sea (2002), the Novogodnee. West Siberia (2006).

Since 1991, he has been conducting joint scientific research with Statoil, Norsk Hydro, Verbundnetz Gas, YUKOS, SIDANKO, Lukoil, Rosneft, TNK-BP and other companies.

To increase the efficiency of field development, more and more wells are drilled with horizontal or high angle section at the end (HAHZ). Despite this, well logging data analysis is based on methodic and models developed using data from vertical and slant wells with relatively low inclination angle. Although it works well for vertical wells, it does not take into account geometric effects associated with high angle of drilling where wells are drilled almost parallel to formation layers. That often leads ambiguities while logging data analysis and formation evaluation in HAHZ wells compared to low angle wells. This fact does not allow using logging data from horizontal wells for geological and hydrodynamic models, which reduces its credibility.

The presentation describes uncertainties that exist when using conventional processing and interpretation techniques in horizontal wells and their causes. For demonstration purpose, the paper uses an example from real well, which has been drilled horizontally in complex environment in one of the field of Western Siberia region of Russia.

Azimuthal measurements application together with advanced modeling software packages enable more reliable estimation of well length exposed to reservoir, spatial position of its boundaries and essential reservoir properties, such as porosity and saturation. As a result, the geological model may be refined locally.

Author:

Bokarev Anton, Schlumberger

Anton was graduated as Oil ang Gas geologist in the Tyumen Industrial University in 2008. At Schlumberger, he has taken the path from the Field Engineer to the international Logging-While-Drilling instructor. He took part in projects in Western and Eastern Siberia, the Timano-Pechora and Caspian regions. Has experience working for foreign projects in the UAE and Oman. Currently he holds the position of Senior Petrophysicist at Schlumberger in Tyumen. The field of expertise of the author is the Logging While Drilling technologies and its practical application. He is the author of 10 scientific articles and patents. Has experience working and teaching abroad.

 

Event will take place on December 4,Monday, at 1830 hours.

Gathering guests at 18.30 in the Congress Center of the RF CCI, entrance by invitation.

In order to receive an invitation, please write to This email address is being protected from spambots. You need JavaScript enabled to view it., the letter should indicate your full name, place of work and position.

Applications are accepted until 12.00, on 30 November.

With the increasing importance of the cost of projects FPP stage to minimize the geological and technical risks associated with the full-scale development of deposits only increases. An integrated approach multidisciplinary group based on detailed modeling to study the formations fluids and potential wells at the stage of FPP, based on the disparate and often conflicting data, allows you to develop metrology and other requirements for conducting research to develop an optimal design, successfully conduct himself step FPP narrow source uncertainty range and improve the expected development indicators.

For reliable identification of the parameters of the object (deposit, field) at the stage of field pilot projects (hereinafter - FPP) are equally needed at least two components - the information content measurement system response and detailed modeling of planned processes of the FPP. This makes it possible not only to create a design study, but further optimization FPP plans, with no loss of accuracy or completeness of the expected results. The results of the implementation of this approach for one of the Arctic projects (complex hydrodynamic studies of wells - well testing, including Interference) are interested.

Based on the detailed geological and hydrodynamic modeling of the FPP well tests, the sensitivity of the production parameters to the base reservoir and fluid properties is estimated. Consideration of a wide range of uncertainties related to the sedimentation, the facial structure of the reservoir, development parameters, technological and infrastructure constraints, makes it possible to rank the most important uncertainties and to correct the FPP if necessary.

Detailed simulation in this case gives a numerical evaluation of the expected program results (for example, variations of bottomhole pressure responses to the initial perturbations of the main parameters, the duration of well tests etc.). This approach provides a wide opportunity for developing metrological requirements, as well as an appropriate well test plan and a well test design with a minimum risk of loss of data quality.

Author

Diana Shigapova, PhD

Roxar, Head of Oil&Gas Reservoir Development Division

In 2005 Diana graduated from the Russian State University of Oil and Gas named by IM. Gubkin on the specialty "Hydromechanics of oil and gas condensate fields". In 2009 she defended her Ph.D. on the specialty "Fluid, Gas and Plasma Mechanics". Author and co-author of more than 30 publications and reports at conferences.

Since 2005 Diana has specialized in reservoir engineering. In Roxar since 2007 she has passed the way from a reservoir engineer to a head of the division. The portfolio of projects includes works on more than 50 fields of the Volga-Ural, Timano-Pechora, West-Siberian, incl. Yamal, and the Caspian regions both for large vertically integrated and for small companies.

Diana’s expertise is E&P projects based on 3D reservoir modeling and simulation: field development strategy, assessment of investment attractiveness, geological prospecting works / pilot programs, drilling justification, localization of residual reserves, field development optimization (including waterflooding, workovers, wellbore treatment, formation treatment etc), uncertainty evaluation and risk analysis.

In SPE since 2006, an active participant in SPE events, a program committee member of the SPE Caspian Technical Conference & Exhibition.

Attention!
Next Moscow Section meeting was rescheduled from October,10 to October,4.
We will be waiting for you at 7 p.m. in Congress Center of RF CCI.
For more information please follow the link.

The choice of the optimal development method for low permeability reservoirs has been a major challenge for most oil companies in recent years. 

Gazprom Neft target oriented production is 100 million tons/year. This can be achieved through the commissioning of new assets.


 Please click here to download presentation. Access for SPE members only.

The current economic situation, as well as the lack of highly profitable reserves, make more attention to new investment projects. It is necessary to estimate correctly the costs of developing new assets to make the right management and technical decisions in order to maximize the effect of invested funds, involving low-margin and hard-to-recover reserves.

 

Goals and targets

Cost engineering aims to improve the consistency of capital and operating cost evaluation at the early stages of project implementation.

1.     Make checklist of existing methods and different software of cost evaluation at the early stages of project implementation.

2.     Define ways how to improve the consistency of capital and operating cost evaluation

3.     Create the “Cost model” bringing together the opportunity to evaluate capital and operating costs in order to make comprehensive cost assessment.

4.     Achieve high level of automation - implement cost engineering tools on special IT platform

 

Cost models

The analysis of cost software show that existing cost software do not provide the necessary level of accuracy. The cost software has been developed in Gazprom Neft since 2014.

 

Results and conclusion

The developing tools of the capital and operating costs assessment do not have analogues in Russia. Today company Gazprom Neft develops first-of kind software in the oil and gas industry. The first results of utilizing cost tools show the need of total costs analysis for making effective business decisions during the project life. As a result every correct solution from the issue based on the comprehensive cost assessment help to achieve the company strategic goal to produce one hundred million tons of oil.

 

The most important results are:

1.      The software analysis of cost engineering tools was carried out.  There are no special costs tools for detailed calculation.

2.      It was decided to develop their own costs tools based on the decomposing method. This method improves the quality of costs calculations.

3.      The capital expenditures’ assessment tool is developed and used during the concept design.

4.      The operating expenditures’ assessment tool is developed too with detailed cost units.

5.      The potential effect of utilizing these tools can achieve more than 1.5 billion of rubles just from.

1.        6.         In the near future costs tools will be realized on the special IT platform which gives opportunity to improve the accuracy of costs assessment.

 

1.      Authors:

Pashkevich Lev Aleksandrovich

Chief Specialist, Gazpromneft Science & Technology Center

 

Was born in 1989 in Tyumen.

Studied development and exploitation of oil and gas fields in Tyumen Oil and gas State University.

From 2011 – 2014 worked in «TNK-Uvat» as chief specialist in department of field development planning. Разработка единой цифровой модели на базе PIPESIM. Developed a digital model based on PIPESIM.

From 2014 – 2015 worked in «TNK-Uvat» as chief specialist in department of integrated projects, was engaged in different integrated projects and development of field concept.

From 2015 to current time work as chief specialist in costs engineering department. The basic professional interest connect with cost assessment for oil and gas fields and development the unique cost software.

Engage in science activity; participate in science technology conferences, published in «Neftyanoe Khozyastvo», «OnePetro», «PROneft».

Khlyzova Kristina Vyacheslavovna

Leading Specialist, Gazpromneft Science & Technology Center

 

Was born in 1991 in Tyumen.

Studied economics in Tyumen State University and sustainable management in University of Nordland.

From 2015 to current time work as chief specialist in cots engineering department. The basic professional interest connect with cost assessment for oil and gas fields and development the unique cost software.

Engage in science activity; participate in science technology conferences, published in «Neftyanoe Khozyastvo», «OnePetro», «PROneft».

 

Managed pressure drilling as an effective solution for wiring wells in conditions of catastrophic absorption in fractured reservoirs.


Managed pressure drilling (MPD) implies dynamic control of equivalent static and circulating densities (ESD and ECD) depending on the actual drilling conditions and objectives, gives an undeniable advantage when the use of lost circulation materials does not bring the expected effect and adversely affects the drill-in quality of the reservoir.

The drilling of the Riphean deposits of the Yurubcheno-Tokhomsky field is closely linked with catastrophic lost circulations due to the natural fracturing of the productive reservoir and low reservoir pressures. Most of the wells were not drilled to the target depth due to complications associated with lost circulation. In addition, well flow rates often did not reach planned values.

The application of MPD technology allowed to ensure successful drilling of horizontal well intervals in the fractured reservoir of Riphean deposits and significantly increased productivity of new wells.

While pilot project of MPD technology testing in 2016, 4 wells were drilled, each of which required a completely individual approach and technological flexibility. To date, the MPD technology has proven its effectiveness and made decision to continue its application in field. 

Author:

Pavel Dobrokhleb

Technical Sales Engineer

Schlumberger

In 2006 he graduated from the Gubkin Russian State University of Oil and Gas. He began his career in 2006 with M-I SWACO from the position of drilling fluids engineer. 

Then he worked on various engineering and management positions on projects in Western Siberia.

From 2012 to 2016 he worked as an expert at the Petro-Technical Engineering Center of Schlumberger and supported key drilling projects on land.

Now, involved in the sales development of drilling fluids and Dynamic pressure management technology in Russia.

Member of industry conferences and author of a series of publications on drilling in complex conditions.