ONSHOREIN A NUTSHELL EXPERTISE & TECHNOLOGY

2009

TOTAL'S OPERATED ONSHORE ASSETS

Liquid production capacitykb/d: thousand barrels per day

Gas production capacityMcu.m/d: million cubic meters per day

1964

Acquisition

1993 2002 2006 2010 2012 2014 2017 2018 2018

NigeriaNLNG - JV Onshore - OML58

ArgentinaNeuquen

ItalyTempa Rossa

BoliviaIncahuasi

US(Unconventional - Barnett)

Uganda(Upstream - Tilenga)

Papua New GuineaPRL 15 Upstream

Uganda/TanzaniaEACOP (Midstream)

KazakhstanDunga

UAEUnconventional Diyab

16.2Mcu.m/d 27.2 Mcu.m/d 0.6 Mcu.m/d 11.3 Mcu.m/d 104 Mcu.m/d 0.9 Mcu.m/d 27.1 Mcu.m/d NA NA 0.6 Mcu.m/d43 kb/d 30 kb/d 50 kb/d 10 kb/d NA 204 kb/d 16 kb/d NA 20 kb/d NA

196640%

Start-up:Share:

199531%

201950%

201650%

200490.5%

202456.67%

202740.1%

202472%

200060%

2025+40%

Today, onshore activities account for 44% of Total’s production, with 1.3 million boe/d. Onshore, which constitutes approximately 60% of the Group’s reserves, is characterized by the high level of diversity of sites that are developed in harsh environments, such as the deserts of Algeria and the UAE, the primary forest of Papua New Guinea, the urban environment of Barnett (US) or the hostile permafrost conditions

in the Northern Arctic Circle in Russia. The produced fl uids range from heavy to light oil and from gas condensate to dry gas, the reservoirs ranging from conventional to tight and unconventional.

U nconventional projects play a key role in Total’s onshore

activities and include a wide-ranging diversity of reservoirs containing oil and gas from shale , tight and coalbed methane. Vaca Muerta (in Neuquén, Argentina), Total’s fi rst operated shale asset, is one of the biggest unconventional fi nds in the world, covering a surface area of around 30,000 sq. km. The learning curves from the

UNCONVENTIONALAND CONVENTIONAL

Group’s unconventional well operations, such as the 2,700 wells in Barnett, are applied to conventional developments such as Tilenga (Uganda), which will be equipped with compact pads and where factory drilling techniques are used to accelerate drilling of over 400 wells. Custom-made wells are no longer used for such developments, which favor simplifi ed techniques, standardized materials and procedures. Detailed

performance improvement processes are implemented to optimize the time spent on every operation and boost effi ciency. The Group has also gained a high level of expertise in early production facilities used to de-risk and phase developments and speed up activities to reduce time to market, with discovery to fi rst gas achieved in only two years, as in Dyab (UAE) and Rincon la Ceniza (Neuquén).

DIVERSE RESOURCES, DIVERSE CHALLENGES

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LOCAL ACCEPTABILITY

In onshore activities, initiatives are deployed to limit impact on the local population and environment. The electrifi cation of well pads, drilling rigs and central processing facilities from the national grid, together with improved energy effi ciency

technologies, contribute to GHG reduction. Another contributor to the reduction of our carbon footprint and energy optimization is the solarization of some of our onshore assets. At Tempa Rossa, in Italy’s Sauro valley, produced water is treated to very stringent specifi cations and is used to supply the demineralization unit or as fi rewater. Diyab, an unconventional gas play to the west of the ADNOC onshore concession in Abu Dhabi, adopts a minimum fl aring policy, the reduction and reuse of water for well fracking, the solarization of well pads etc. Expertise and new techniques have provided numerous solutions on onshore installations. For example, drones were deployed in the OML 58 fi eld in Nigeria for fl ooding evaluation (and security patrols). In Italy, the use of robots for inspection and remote well-pad access has been successfully geared towards preventing personnel exposure to certain hazardous situations as well as reducing maintenance costs.

2 3

Total holds the world record length for an onshore vertical well, drilled at Tempa Rossa in Italy

7,148 meters Key Figures

Vaca Muerta, Neuquén Province, Argentina.

Tilenga, Uganda.

ENHANCED OIL RECOVERYPOLYMER INJECTION

BIG DATA

STIMULATED ROCK VOLUME (SRV)

Total is a leading pioneer in Enhanced Oil Recovery (EOR)

techniques and reached a technological milestone by successfully injecting a cost eff ective new-generation polymer (SAV10) into the ASAB onshore carbonate reservoir in Abu Dhabi. This process boosts oil recovery and maximizes production, while also reducing the carbon footprint. In 2019, Total and ADNOC injected 70 tons of SAV10 into the ASAB fi eld, a world fi rst. As a result, an extra 7% of oil (250 million additional barrels) is possible when deployed!

SRV refers to the volume of hydrocarbon-bearing rock that is stimulated by pumping large volumes of water and sand at high pressures into the formation. This

hydraulic fracturing (or “fracking”) is used in tight to ultra-tight reservoirs and plays an important role to achieve commerciality in a number of the Group’s onshore assets in Argentina, Algeria and the UAE, for example. It aims at delivering maximum stimulation benefi t at the minimum cost, to create artifi cial reservoirs to produce hydrocarbons from the tight formations.Fracking is often required to extract unconventional resources commercially, and some ultra-tight rocks, sometimes referred to as “unconventional”, will not fl ow at all without systematic fracturing. The Total's onshore team has developed a specifi c SRV know-how to better control fracking operations and ultimately enhance recovery of hydrocarbons from tight plays with the minimum possible number of optimally-positioned wells.SRV-integrated workfl ows are applied at various stages of the maturity of a play, from exploration to development. They forecast every step in the lifespan of our plays to streamline processes to be prepared for several possible scenarios. They enable us to determine the most optimal parameters before, during and after the fracking process. Based on the geological and geomechanical features of the rock, they provide an indication of the optimal conditions for our processes.

So how does polymer injection work? In the case of the Thamama B reservoir, the upper section is 50 times more permeable than the lower section. This means that when water is injected into the reservoir, not all of the oil is recovered in the lower section. Injecting the SAV10 polymer into the interface between the two sections enables the water in the lower section to untrap the remaining oil and sweep it up to the wells. Waste is kept to a minimum by re-injecting any fraction of back-produced polymers into the reservoir. As a result of this polymer injectivity

test success, Total has become a reference for polymer EOR with its partner ADNOC. The utilization of the polymer injection technique has yielded commendable results where carbon emissions are concerned, and it minimizes the produced water volume. On the Tilenga project in Uganda, polymer injection will help reduce emissions of 16 kg CO2

equivalent/bbl to 13 kg CO

2 equivalent/bbl, while

on the ASAB fi eld, emissions were halved down to only 7 kg CO

2e/bbl (including

emissions due to polymer manufacturing and transport).

Many of Total’s onshore fi elds are very mature and were developed with numerous wells. This generates a

huge amount of data over the years. This data is crucial for understanding the fi eld’s dynamic behavior and for a proper management of the reservoir and subsequent production. The well production data (daily oil output, water and gas rate, pressure at well head etc.) is incorporated into the dynamic model and reproduced as closely as possible with the simulator (history matching phase). To perform an adequate history match, a good 2G&R (Geophysics, Geology & Reservoir) synthesis must be performed. Various scenarios can be tested and the development of the fi eld can be optimized with a technical-economic study. The main challenge in big data is to assess the quality of the data and correct it if inaccurate. Managing the data presents a signifi cant challenge, as it is important to get the most out of it. Some fi elds use highly organized databases, while for others, preliminary work on restructuring the data needs to be carried out. Analyzing big data is facilitated by state-of-the art tools available on the market and ambitious tools developed in-house to meet the specifi c needs of engineers and geoscientists of Total, such as Sismage CIG, Intersect, T-more, Fast Reservoir Forecaster (FRF).

NEW HEIGHTS OFTECHNICAL EXPERTISE

Total has developed a wide range of customized design solutions and equipment, maintaining a very high operating effi ciency of nearly 95% in onshore operated

facilities even in extreme conditions. The deployment of polymer injection (EOR), big data, stimulated rock volume, compact plant and well pads are good examples of

this technical expertise implemented in onshore activities.

A s part of the Onshore Technological Roadmap, two projects were initiated targeting

the promotion of compact concepts in our installations to reduce costs and our environmental footprint.The fi rst project is about ‘Compact Plant’. A broad analysis of onshore plants was conducted to check if space usage was optimal, considering multiple criteria related to safety distances and layout complexity. The target was to identify what drives gains in making onshore plants more compact. A ‘Compactness Index’ was introduced and calculated for

numerous types of assets: onshore, off shore, FPSOs, refi neries etc. Three main categories were identifi ed: extended/conventional/compact plants and parametric studies were carried out, which demonstrated, to a certain extent, the potential for cost savings such as on Tempa Rossa (Basilicata region in South Italy)

COMPACT PLANT AND WELLPADS with 2% ultimate capex savings directly linked to a 15% surface reduction. As a result, a formal monitoring and effi cient optimization of the onshore units’ surface is introduced at very early study phases and an eff ort is maintained during the project’s subsequent development and challenged at key layout and 3D model review stages. The second project, called ‘Well-pad Optimization’, aimed to improve the design of onshore drilling pads while maintaining reliable and safe operations. A simple and effi cient design was achieved via the contextualization of onshore safety engineering principles, layout optimization by reviewing safety and operation distance defi nition criteria, cost-effi cient well monitoring and alternatives to power supply in remote locations. The application of these improvement principles during the diff erent design and construction phases of the Incahuasi wellpads (Bolivia) was a big success as capex was slashed by around 60%.

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Polymer injection: emissions halved on the

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Key fi gures

The ASAB onshore carbonate reservoir, Abu Dhabi.

Package well design, Incahuasi, Bolivia.

A cquired in 2018, the 6,150-sq. km Diyab shale play was the first unconventional gas project

to be signed with an IOC in the Middle East, which is kudos to Total’s expertise. Jointly operated by Total (40%) and ADNOC (60%), the project is now in Period 1, with the drilling of four wells, leading to the first delivery of the unconventional gas. Period 2 is to be sanctioned in November 2021, over four years, prior to Period 3 and full field development. At Diyab, the teams are faced with the challenges of HP/HT drilling projects and a de-risking of the resources was carried out to estimate how much gas could be produced and what the corresponding value is in such a large exploitation area.The production pipeline, built in only two years, allows early production gas to be transported to the facilities instead of being flared. This fits in with the Zero Routine Flaring initiative launched by the World Bank. Diyab’s other ecological initiatives include the utilization of sea water for drilling and completion operations and the grouping of well pads to limit the surface carbon footprint. Diyab is targeting an extraction rate of 1 billion cubic feet of gas per day.

ONSHORE PROJECTS

Total’s recognized experience in managing large and complex projects began with onshore historical fields and since then has embraced harsh offshore and deepwater developments.

Mastering design and execution with minimum impact on the environment is not limited to our operated assets, but is also a benefit to our partners and host countries in operated-by-others assets (OBOs). Sharing our best practices to safely deliver responsible and profitable projects

on schedule around the globe is our daily challenge and involves hundreds of vendors and contractors working hand in hand with our teams. Carbon footprint mitigation is at the heart of

our existing facilities, incorporating energy efficiency improvement and flaring reduction programs. All new projects are designed with maximized electrification, including drilling rigs using renewable

power and zero emissions. Our aim is to give our onshore plants Total brand status.

DIYAB, ABU DHABI

TEMPA ROSSA, ITALY

O perated by Total E&P Italy (50%) and its partners Mitsui (25%) and Shell (25%), Tempa

Rossa comprises six wells drilled to a depth of 7,148 meters, equipped with a double electric pump system. Each well has been designed to produce between 8,000 and 15,000 barrels of oil per day. The site is equipped with a highly sophisticated oil center and process systems, with an acid gas removal unit, sulfur removal unit and an LPG unit, the complexity of which presented a considerable challenge for start-up. Harsh winter conditions pose another operational hurdle. Due to the relief and high seismicity of the zone, the work required the excavation of 2.5 million cubic meters of earth as well as soil drainage and stabilization. A total of 5,000 piers were buried to build the 50,000 b/d hydrocarbon processing center. The "Val d'Agri-Tarente" pipeline transports the oil from the processing center. It connects the neighboring facilities in Val d'Agri to the Taranto refinery and its export terminal.

T he giant Lake Albert onshore oil development project,

located north-west of Uganda, in which Total signed a farm-in agreement in 2012, shall develop around 1 billion barrels of oil via the Tilenga and Kingfisher upstream developments and the 1,443-km midstream EACOP pipeline, which will transport the stabilized crude oil from Uganda to the port of Tanga in Tanzania. First oil is expected before end-2024.Tilenga, operated by Total (66.7%, alongside CNOOC, 33.3%), includes

LAKE ALBERT, UGANDA/TANZANIAthe development of several shallow-reservoir fields, with more than 400 wells from around 30 well pads. The production will be processed at a Central Processing Facility (190 kbpd at plateau). A company, EACOP (East African Crude Oil Pipeline), has been created to build and operate the pipeline from Kabaale in Uganda to the port of Tanga in Tanzania, with associated above-ground installations and marine storage/export terminal and jetty. This is the world’s longest thermally insulated and heated pipeline.

The crude blend must be maintained at >50°C for transportation. It is the world’s longest heated crude oil pipeline. The mitigations of the H3SE risks associated with the project are thoroughly developed in action plans with specific attention to the environment: a no flaring policy, an ambitious long-term net gain biodiversity action plan, and societal plans related to the livelihood, restoration and improvement program for people affected by the project.

Total E&P Kazakhstan has a 16.81% interest in the North Caspian Sea PSA consortium, which owns the Kashagan field (35 billion barrels of oil and 100 TCF of gas). North

Caspian Operating Company (NCOC) is the operator, with KMG (16.88%), Exxon, Shell, ENI and Total (16.81% each), CNPC (8.33%) and Inpex (7.56%). Kashagan is a technically complex field due to its location in the Caspian Sea, where the shallow water freezes into irregular formations for half the year, and 15% of H2S in the well fluid. Kashagan’s oil and gas are produced from a very high-pressure (700 barg) and high-temperature (150°C) reservoir. Commercial production started in 2016 and the facilities currently in operation are part of the Experimental Production Phase, with a production capacity of 400 kb/d of oil. In 2017, the operating consortium defined a set of goals known as the “four fives”: to produce 500,000 b/d within five years, at an opex of less than $5 a barrel and less than 5% unplanned shutdowns. The offshore facilities abide to a policy of zero reject into the Caspian Sea, as no production water disposal is authorized, and GHG emissions are strictly monitored by the authorities. Kashagan applies a zero routine flaring policy and non-routine flaring is far below the authorized annual quota. Further development projects and related studies are ongoing to

maximize the use of existing facilities and manage more gas, in order to increase production to full capacity.

KASHAGAN, KAZAKHSTAN

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Tilenga, Uganda.

Kashagan, Kazakhstan.

TOTAL S.A.

Share capital: 6,632,810,062.50 euros 542 051 180 RCS Nanterre

Exploration & Production – Paris Phone: +33 (0)1 47 44 45 46 2, place Jean Millier – La Défense 6 92078 Paris La Défense Cedex – France

Exploration & Production – Pau Phone: +33 (0)5 59 83 40 00 Avenue Larribau – 64018 Pau Cedex – France

www.ep.total.com

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Total is a broad energy company that produces and markets fuels, natural gas and electricity. Our 100,000 employees are committed to better energy that is more affordable, more reliable, cleaner and accessible to as many people as possible. Active in more than 130 countries, our ambition is to become the responsible energy major.

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