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CALL FOR INTEREST Workshop with HQ:

LUKOIL Projects on Caspian and Baltic Seas ‐ new developments and MMO

25 March 2020 in Moscow, (date TBC)

Topics for the workshop received from LUKOIL:

№ Topics п.п.

Project Management Modern contract types for projects‐the potential to reduce risks for the implementation of 1 projects within the terms and budget (Alliance, ЕРС, EPCM, FC) Reduction of offshore project risks using the project management methodology developed by the 2 company. TechnipFMC Place of the plant model in integrated production management/production optimization projects, 3 application, tasks to be solved, effects, implementation/implementation difficulties; Optimization of production in real time using integrated modeling tools, experience of the Norwegian 4 industry Systems of motivation and improvement of staff competencies, comprehensive training programs, 5 rotation and monitoring. Unmanned Technology

Unmanned technology. Classification of structures by unmanned technology (unmanned, with periodic visits of personnel, etc.). Hierarchy of complexity of the top sides of wellhead platforms and 6 the principles of choosing the optimal design for a particular project (for example, for D33 or WHP on Kuvykin) Certification and standardization issues, regulatory documentation for remote operated platforms‐ 7 current status and planned changes Experience in design and of projects on remote operated fields like Valhall Flank West, 8 Jackdaw. Potential for unification of solutions for unmanned technologies. Database of standard solutions in design. The list of systems and equipment of unmanned platforms with remote control and frequency of 9 visits, including for maintenance. Applied products for predictive analysis of equipment condition of remote operated platforms and evaluation of efficiency of their application. 10 Unmanned technology. Automation, control and telemetry systems on the top side. Advanced implemented technologies in the field of automation for remote restart/start‐up of 11 technological systems and power supply systems, start‐up and output to the technological mode of various systems of unmanned platforms. Experience of application uninterruptible (autonomous) power supply on small platforms such as 12 "subsea on a stick" and regular large "unmanned" platforms. Requirements for additional equipment of typical dynamic equipment for operation on unmanned 13 platforms; The use of remotely controlled autonomous mobile systems (robots) on offshore platforms with the 14 application of platform remote operation What is the control effect on the equipment and mechanisms on unmanned platforms? What is the 15 period of autonomy of the platforms? Statistics of unscheduled shutdowns in depending on the type of remote operated platform – 16 wellhead platform or regular platform. 17 Safety systems at offshore oil and gas facilities. 18 Fire safety system on unmanned platform. Special requirements for the available technical equipment of vessels for servicing offshore platforms 19 with unmanned operations Subsea pipelines, tie‐ins, multiphase pipelines, fiber optic lines

20 Design and joint laying of subsea pipelines and fiber optic cables (fiber‐optic communication lines).

21 Experience in performing crossings of subsea pipelines.

Experience in application of various materials for subsea pipelines transporting multiphase products 22 containing aggressive components (hydrogen sulfide, carbon dioxide);

23 Methods of diagnostics of subsea pipelines from bimetallic and composite pipes;

24 Advanced technologies for repair of subsea pipelines, including those with concrete ballast coating;

Calculation of multiphase pipeline systems, design problems and subsequent monitoring during 25 operation. As an example of the fields Ormen Lange and Snøhvit. Experience in designing and operating onshore multiphase pipeline in cold climate zones with a 26 length of over 80 km. Increase of service life of pipelines‐ application of chemical inhibitors, application of coating materials 27 for protection of internal part of oil pipelines and pipelines with produced water, protection welded connections against the aggressive environment. Technologies

28 and construction of gravity based artificial islands (bulk or concrete)

Design and construction of the topsides for the FPSO. Integration of the upper module with the hull 29 of the FPSO. Application of digital solutions and conveyor principle in FPSO design, construction (FPSO Factory) 30 ММО (maintenance, modification, operation) 31 Modern methods of installation on the seabed and methods of fixation the platforms to the bottom. Technical solutions and oilfield equipment for production, treatment and transportation of well 32 products for the development of the fields at water depths of more than 1500 meters (ultra‐deep water). Experience in preparation of fuel gas on small platforms such as "subsea on a stick", including from 33 multiphase production of gas condensate field with hydrogen sulfide content up to 600 ppm. Application of technologies for rational use of associated petroleum gas in fields with high rates of 34 growth and decline in production volumes. (project of the fields like Vinogradova, Medium Nazymskoye UC‐2/7, April). Optimization of technological processes, taking into account the compact placement on the platform, 35 as well as subsea operations. 36 Experience in construction and operation of mobile oil and gas treatment plants. 37 Experience of application methanol and MEG regeneration plants Experience in the use of absorption lithium bromide refrigerating machines (ABLRM) for cooling the 38 working air of gas turbine drives on offshore platforms. 39 Experience of application of air cooling in gas compression systems 40 Cathodic protection of steel structures and pipelines. 41 Technical solutions for the installation system and laying of communications. Solutions for accommodation of personnel during completion works offshore at the period of 42 commissioning. Drilling. Overview and principles of selection of offshore drilling systems for various applications. Including 43 standard modern drilling packages, packages for cold regions (including winterization), modular drilling packages, etc.

Parameters of profiles of horizontal wells (depth, intensity of deviation, experience in drilling profiles 44 of multi‐hole wells‐the number of branches, the maximum length, application of tools, well design)

45 Criteria for selecting the length of the horizontal section on ERD well.

46 Experience of drilling wells in the intervals of unstable rocks, mud loss and stuck prevention plan.

Cementing of wells in Arctic conditions, prevention of annulus pressure, technology of balancing 47 annulus pressure, experience in insulation works. The experience of operating wells with annulus pressure. 48 Experience of casing running into well and cementing in severe conditions. Technologies ensuring the quality of cementing (existing statistics on the quality of well cementing, 49 application of additives, optimal time of setting)

50 Requirements for drilling fluids for entering into pay zone, quality evaluation methods.

51 Experience in drilling of multi‐lateral wells of TAML‐3, 4, 5 level. Best examples and technologies Production. Technical solutions for in offshore production: electric centrifugal pumps (ESP), downhole 52 systems; multiphase pumps (MPP)

Experience in operation of smart wells (application of slot liners and effective production control from 53 the top) Enhance of oil recovery of oil fringe (gas injection under OWC, drilling of lateral holes, barrier 54 flooding) A typical scheme of monitoring the development of an offshore field in the (requirements 55 for instrumental measurements, multiphase flow meters, assessment of interval inflow in the horizontal hole, etc.) 56 Diagnostics of annulus pressure and fluid circulation. 57 Insulation work for annulus pressure and fluid circulation. 58 Well production monitoring, application of tracers.

Experience of multizone fracturing in horizontal wells with cemented casing. Applied technologies of 59 completion of wells suitable for multizone fracturing, with possibility of repeating the fracturing.

60 Monitoring of downhole equipment. Equipment and technology for downhole monitoring.

Core elements of predictive analysis of operating equipment on the platform? What is enough 61 number of the monitoring parameters for high‐quality planning and control?

62 Promising areas in offshore oil and gas production. What are the future trends?

63 Experience of field development with the presence of oil fringe and gas cap. Experience of steam / thermal injection into formation at the in the fields with heavy oil and effect of 64 EOR. Applied equipment. Experience in treatment of formation water for the further use in steam generators. Applied 65 equipment. 66 Development of low‐permeability reservoirs of . Development of deposits (sandstones and carbonate reservoirs) containing viscous and highly viscous 67 oil by using thermal and other methods (heaters, steam injection, CO2, etc.) Methods of control and limitation of water coning and water cut in production wells on high‐viscosity 68 oil floating with expansion‐type water‐ drive reservoir. Selection of the last section of the hole (length of horizontal section, number of fracturing ports, 69 distance between ports, type of couplings, type of completion (cemented or not). Applicable hydraulic fracturing design (tonnage, proppant type, flow rate, concentration, guar‐free 70 gels). IT 71 Integrated project management information systems (MIPS). Methodology and software for the construction of geological and hydrodynamic models. Estimation 72 of uncertainties in the construction of the GHDM. Experience Norwegian in modelling and application of complete integrated 73 models of offshore fields.

74 Software products for integrated models used by Norwegian energy companies.

Experience of Norwegian energy companies in the creation/use of digital information models and 75 integrated models in the implementation of projects for the development of offshore fields, the position of models in the phase approach. Applicable modeling software (reservoir / transportation and treatment)? How does integration 76 work? What is the reason for the introduction of in time close to real? At what stages of field development is this technology used? What organizational structure (or role) implemented this 77 technology at the stage of drilling? What technological and economic effects have been obtained in this direction? Issues in management/organization of processes (systems/software for planning and control of 78 supplies, scheduling).

CASPIAN SEA https://www.norwep.com/Market‐info/Priority‐Projects‐Oil‐Gas

LUKOIL has discovered ten fields in the . The total recoverable hydrocarbon reserves of all the fields equal seven billion barrels of oil equivalent.

The company continues to construct facilities at Vladimir Filanovsky, Yury Korchagin and Rakushechnoye fields.

LUKOIL completed construction of the first well as part of Phase 3 of the development of the V. Filanovsky field in the Caspian Sea. The well was drilled with a floating jack up rig Neptune, mounted on a riser block platform.

The newly constructed well has two bores and features TAML level 5 intelligent completion system. The drill depth of the main bore is 3 235 meters. The bottom of the side track is 3 261 meters deep. Planned daily flow rate of oil is 1 838 metric tons.

Produced oil is delivered to the Phase 1 central processing platform via a subsea pipeline. Phase 3, intended to maintain annual oil production at the planned production level of six million metric tons of oil, will integrate western part of the V. Filanovsky field in the development. Operation of the riser block platform is almost automatic and requires minimum involvement of the personnel.

As part of Phase 2 of the construction plan for Yury Korchagin field, the company has completed the fourth well at the wellhead platform with a bottom hole 6,390 meters deep and a horizontal section 4,276 meters long. An intelligent completion system run down the hole of the well, allows real‐time control of operation depending on actual conditions, which contributes to higher efficiency of the recovery of hydrocarbons. As a result of the drilling program implemented as part of Phase 2 of the Yury Korchagin development plan, production of oil went up 27% in the first quarter of 2019 as against the same period of the previous year.

As for Rakushechnoye field, the company performs construction and assembly works, develops technical documentation, procures equipment and materials, and performs hull works on the topsides and substructures of the fixed ice resistant platform and of the accommodation platform. Commercial production of oil at Rakushechnoye field is to begin in 2023. The planned annual production rate is estimated 1.2 million metric tons of oil.

NEW DEVELOPMENT ‐ GAS FILED WITH H2S CONTENT NAMED AFTER YURI KUVYKIN

Yuri Kuvykin gas condensate filed ‐ first gas in 2026; the filed situated in 80 km from Filanovskogo filed 60 km to the shore. Development concept – fixed steel structures. Operation philosophy – unmanned. Water depth 15 m, ice conditions. Reserves = 330 bln.m3; Production = 6,6 bln.m3/year; H2S content 20 ppm; 2019 – pre FEED; FEED 2020; FID 2021.

LUKOIL‐ Nizhnevolzhskneft is operator of the North Caspian license area. LUKOIL – Engineering – Volgograd‐NIPI‐MorNeft in Volgograd is the design institute and general contractor for engineering.

BALTIC SEA

Kravtsovskoe Field https://www.norwep.com/Market‐info/Priority‐Projects‐Oil‐Gas

LUKOIL started to develop offshore Baltic fields in 1995. Kravtsovskoye field (D6) was commissioned in 2004. Exploration and appraisal drilling at D41 was performed from a jack up rig in 2014. Upon registration of the production license for D41 field by Russia’s Ministry of Natural Resources and Environment on April 22, 2016, the active phase of the investment cycle started in November of 2017. Operational drilling commenced on August 2, 2018. It is planned that D33 and D6‐South fields will be commissioned after 2020.

At the moment the project development of D33 structure is on FEED stage. was won EPC contract in 2019. The scope of work is comprising engineering and fabrication of two wellhead fixed steel platforms and pipeline to the shore at 60 km. Sea water depth is 70 – 80 m on D33 area.