Onshore in a Nutshell

ONSHORE IN A NUTSHELL

EXPERTISE & TECHNOLOGY DIVERSE RESOURCES, LOCAL ACCEPTABILITY n onshore activities, initiatives are deployed to limit impact on the local population DIVERSE CHALLENGES and environment. The electrifi cation of well pads, drilling rigs and central processing Ifacilities 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).

Gas processing plant, Field of Aguada Pichana, Neuquén province, Patagonia. © VON DER FECHT FLORIAN /TOTAL plant, Field of Aguada Pichana, Neuquén province, Gas processing In Italy, the use of robots for inspection and remote well-pad access has been successfully geared towards

preventing personnel exposure to certain hazardous of Ngiri 3 rig, Uganda © ZYLBERMAN LAURENT/TOTAL in front Children situations as well as reducing maintenance costs. Tilenga, Uganda.

Vaca Muerta, Neuquén Province, Argentina.

Today, onshore activities account for 44% of Total’s production, with 1.3 million boe/d. Onshore, which UNCONVENTIONAL constitutes approximately 60% of the Group’s reserves, is characterized by the high level of diversity of AND CONVENTIONAL sites that are developed in harsh environments, such as the deserts of Algeria and the UAE, the primary nconventional Group’s unconventional well performance improvement forest of Papua New Guinea, the urban environment of Barnett (US) or the hostile permafrost conditions projects play a key operations, such as the 2,700 processes are implemented in the Northern Arctic Circle in Russia. The produced fl uids range from heavy to light oil and from Urole in Total’s onshore wells in Barnett, are applied to to optimize the time spent on gas condensate to dry gas, the reservoirs ranging from conventional to tight and unconventional. activities and include a wide- conventional developments every operation and boost ranging diversity of reservoirs such as Tilenga (Uganda), eﬃ ciency. containing oil and gas from which will be equipped with The Group has also gained a shale , tight and coalbed compact pads and where high level of expertise in early methane. Vaca Muerta factory drilling techniques are production facilities used to (in Neuquén, Argentina), used to accelerate drilling of de-risk and phase Total holds the world record length for an onshore vertical well, Total’s fi rst operated shale over 400 wells. Custom-made developments and speed up drilled at Tempa Rossa in Italy asset, is one of the biggest wells are no longer used for activities to reduce time to unconventional fi nds in the such developments, which market, with discovery to fi rst Key Figures world, covering a surface area favor simplifi ed techniques, gas achieved in only two 7,148 meters of around 30,000 sq. km. standardized materials years, as in Dyab (UAE) and The learning curves from the and procedures. Detailed Rincon la Ceniza (Neuquén).

Acquisition TOTAL'S OPERATED ONSHORE ASSETS

1964 1993 2002 2006 2010 20092012 2014 2017 2018 2018

Nigeria Argentina Italy Bolivia US Uganda Papua New Guinea Uganda/Tanzania Kazakhstan UAE NLNG - JV Onshore - OML58 Neuquen Tempa Rossa Incahuasi (Unconventional - Barnett) (Upstream - Tilenga) PRL 15 Upstream EACOP (Midstream) Dunga Unconventional Diyab

Start-up: 1966 1995 2019 2016 2004 2024 2027 2024 2000 2025+ Share: 40% 31% 50% 50% 90.5% 56.67% 40.1% 72% 60% 40%

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

Liquid production capacity Gas production capacity kb/d: thousand barrels per day Mcu.m/d: million cubic meters per day 2 3 BIG DATA

© TOTAL UAE © TOTAL any of Total’s onshore fi elds are very mature and were developed with STIMULATED ROCK VOLUME (SRV) NEW HEIGHTS OF M numerous wells. This generates a huge amount of data over the years. This data RV refers to the volume of hydrocarbon-bearing rock TECHNICAL EXPERTISE is crucial for understanding the fi eld’s dynamic that is stimulated by pumping large volumes of water behavior and for a proper management of S and sand at high pressures into the formation. This the reservoir and subsequent production. hydraulic fracturing (or “fracking”) is used in tight to ultra- The well production data (daily oil output, tight reservoirs and plays an important role to achieve water and gas rate, pressure at well head etc.) commerciality in a number of the Group’s onshore is incorporated into the dynamic model and assets in Argentina, Algeria and the UAE, for example. It reproduced as closely as possible with the aims at delivering maximum stimulation benefi t at the simulator (history matching phase). To perform minimum cost, to create artifi cial reservoirs to produce an adequate history match, a good 2G&R hydrocarbons from the tight formations. (Geophysics, Geology & Reservoir) synthesis Fracking is often required to extract unconventional must be performed. Various scenarios can be resources commercially, and some ultra-tight rocks, tested and the development of the fi eld can sometimes referred to as “unconventional”, will not fl ow at be optimized with a technical-economic study. all without systematic fracturing. The Total's onshore team The main challenge in big data is to assess the has developed a specifi c SRV know-how to better control quality of the data and correct it if inaccurate. fracking operations and ultimately enhance recovery of Managing the data presents a signifi cant hydrocarbons from tight plays with the minimum possible challenge, as it is important to get the most number of optimally-positioned wells. out of it. Some fi elds use highly organized SRV-integrated workfl ows are applied at various stages of databases, while for others, preliminary work on the maturity of a play, from exploration to development. restructuring the data needs to be carried out. They forecast every step in the lifespan of our plays to Analyzing big data is facilitated by state-of-the streamline processes to be prepared for several possible art tools available on the market and ambitious scenarios. They enable us to determine the most optimal tools developed in-house to meet the specifi c parameters before, during and after the fracking process. needs of engineers and geoscientists of Total, Based on the geological and geomechanical features

The ASAB onshore carbonate reservoir, Abu Dhabi. such as Sismage CIG, Intersect, T-more, Fast of the rock, they provide an indication of the optimal Reservoir Forecaster (FRF). conditions for our processes.

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 COMPACT PLANT AND WELLPADS this technical expertise implemented in onshore activities. s part of the Onshore with 2% ultimate capex savings directly Key fi gures Technological Roadmap, two linked to a 15% surface reduction. As a projects were initiated targeting result, a formal monitoring and effi cient Polymer injection: A the promotion of compact concepts optimization of the onshore units’ emissions halved on the ASAB fi eld to only in our installations to reduce costs and surface is introduced at very early study ENHANCED OIL RECOVERY our environmental footprint. phases and an eff ort is maintained POLYMER INJECTION The fi rst project is about ‘Compact during the project’s subsequent 7 kg Plant’. A broad analysis of onshore development and challenged at key otal is a leading So how does polymer test success, Total has become plants was conducted to check if layout and 3D model review stages. pioneer in Enhanced injection work? In the case a reference for polymer EOR space usage was optimal, considering The second project, called ‘Well-pad CO2e/bbl T Oil Recovery (EOR) of the Thamama B reservoir, with its partner ADNOC. multiple criteria related to safety Optimization’, aimed to improve techniques and reached a the upper section is 50 times The utilization of the polymer distances and layout complexity. The the design of onshore drilling technological milestone by more permeable than the injection technique has target was to identify what drives pads while maintaining reliable successfully injecting a cost lower section. This means that yielded commendable results gains in making onshore plants more and safe operations. A simple and eff ective new-generation when water is injected into the where carbon emissions are compact. A ‘Compactness Index’ effi cient design was achieved via polymer (SAV10) into the ASAB reservoir, not all of the oil is concerned, and it minimizes was introduced and calculated for the contextualization of onshore onshore carbonate reservoir in recovered in the lower section. the produced water volume. numerous types of assets: safety engineering principles, layout Abu Dhabi. This process boosts Injecting the SAV10 polymer On the Tilenga project in onshore, off shore, FPSOs, optimization by reviewing safety and oil recovery and maximizes into the interface between the Uganda, polymer injection refi neries etc. Three main operation distance defi nition criteria, production, while also two sections enables the water will help reduce emissions © TEP Bolivia categories were identifi ed: cost-effi cient well monitoring and

reducing the carbon footprint. in the lower section to untrap of 16 kg CO2 equivalent/bbl to extended/conventional/ alternatives to power supply in remote

In 2019, Total and ADNOC the remaining oil and sweep it 13 kg CO2 equivalent/bbl, while compact plants and parametric locations. The application of these injected 70 tons of SAV10 into up to the wells. Waste is kept on the ASAB fi eld, emissions studies were carried out, which improvement principles during the the ASAB fi eld, a world fi rst. to a minimum by re-injecting were halved down to only demonstrated, to a certain diff erent design and construction

As a result, an extra 7% of oil any fraction of back-produced 7 kg CO2e/bbl (including extent, the potential for cost phases of the Incahuasi wellpads (250 million additional barrels) polymers into the reservoir. As a emissions due to polymer Package well design, savings such as on Tempa Rossa (Bolivia) was a big success as capex is possible when deployed! result of this polymer injectivity manufacturing and transport). Incahuasi, Bolivia. (Basilicata region in South Italy) was slashed by around 60%.

4 5 DIYAB, ABU DHABI TOTAL UAE SERVICES TOTAL ONSHORE © cquired in 2018, the 6,150-sq. km Diyab shale play was the PROJECTS A 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

Drilling rig, Jobi-D, Uganda. © ZYLBERMAN LAURENT/TOTAL 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.

Tilenga, Uganda.

Total’s recognized experience in managing large and complex projects began with onshore KASHAGAN, KAZAKHSTAN 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 otal E&P Kazakhstan has a 16.81% interest in the North TEMPA ROSSA, ITALY Caspian Sea PSA consortium, which owns the Kashagan operated assets, but is also a benefit to our partners and host countries in operated-by-others T field (35 billion barrels of oil and 100 TCF of gas). North perated by Total E&P Italy assets (OBOs). Sharing our best practices to safely deliver responsible and profitable projects Caspian Operating Company (NCOC) is the operator, with (50%) and its partners Mitsui on schedule around the globe is our daily challenge and involves hundreds of vendors and KMG (16.88%), Exxon, Shell, ENI and Total (16.81% each), CNPC O (25%) and Shell (25%), Tempa contractors working hand in hand with our teams. Carbon footprint mitigation is at the heart of (8.33%) and Inpex (7.56%). Kashagan is a technically complex Rossa comprises six wells drilled to a field due to its location in the Caspian Sea, where the shallow depth of 7,148 meters, equipped with our existing facilities, incorporating energy efficiency improvement and flaring reduction programs. water freezes into irregular formations for half the year, and 15% a double electric pump system. Each All new projects are designed with maximized electrification, including drilling rigs using renewable of H2S in the well fluid. Kashagan’s oil and gas are produced well has been designed to produce power and zero emissions. Our aim is to give our onshore plants Total brand status. from a very high-pressure (700 barg) and high-temperature between 8,000 and 15,000 barrels of (150°C) reservoir. Commercial production started in 2016 and oil per day. The site is equipped with the facilities currently in operation are part of the Experimental a highly sophisticated oil center and Production Phase, with a production capacity of 400 kb/d of oil. process systems, with an acid gas In 2017, the operating consortium defined a set of goals known removal unit, sulfur removal unit and LAKE ALBERT, UGANDA/TANZANIA as the “four fives”: to produce 500,000 b/d within five years, at an LPG unit, the complexity of which an opex of less than $5 a barrel and less than 5% unplanned presented a considerable challenge he giant Lake the development of several The crude blend must be shutdowns. The offshore facilities abide to a policy of zero for start-up. Harsh winter conditions Albert onshore oil shallow-reservoir fields, with maintained at >50°C for reject into the Caspian Sea, as no production water disposal is pose another operational hurdle. Tdevelopment project, more than 400 wells from transportation. It is the authorized, and GHG emissions are strictly monitored by the Due to the relief and high seismicity located north-west of around 30 well pads. The world’s longest heated authorities. Kashagan applies a zero routine flaring policy and of the zone, the work required the Uganda, in which Total production will be processed crude oil pipeline. non-routine flaring is far below the authorized annual quota. excavation of 2.5 million cubic meters signed a farm-in agreement at a Central Processing The mitigations of the Further development projects and related studies are ongoing to of earth as well as soil drainage and in 2012, shall develop around Facility (190 kbpd at plateau). H3SE risks associated with maximize the stabilization. A total of 5,000 piers

1 billion barrels of oil via A company, EACOP (East the project are thoroughly NCOC use of existing were buried to build the 50,000 b/d © the Tilenga and Kingfisher African Crude Oil Pipeline), developed in action plans facilities and hydrocarbon processing center. The upstream developments and has been created to build with specific attention to the manage more "Val d'Agri-Tarente" pipeline transports the 1,443-km midstream and operate the pipeline environment: a no flaring gas, in order the oil from the processing center. It EACOP pipeline, which will from Kabaale in Uganda policy, an ambitious long- to increase connects the neighboring facilities in transport the stabilized crude to the port of Tanga in term net gain biodiversity production to Val d'Agri to the Taranto refinery and oil from Uganda to the port of Tanzania, with associated action plan, and societal full capacity. its export terminal. Tanga in Tanzania. First oil is above-ground installations plans related to the livelihood, expected before end-2024. and marine storage/export restoration and improvement Tilenga, operated by terminal and jetty. This is the program for people affected Total (66.7%, alongside world’s longest thermally by the project. CNOOC, 33.3%), includes insulated and heated pipeline. Kashagan, Kazakhstan.

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