//. the Know-how series
ExPLOrATiOn ExPLOrA TiOn & PrOducTiOn
soUr GAs
A history of ExpErtisE
//. Contents
soUr GAs A history of ExpErtisE sss pae 3 foreword pae 4 Context 40% e ’ ’ ae a eev eeve e a. pae 6 ChAllenGes se e laq ve, ta a ve ve a evee ee. pae 8 expertise Ae mdEA, se® e a e a e eza a- a eeve. p. 10 lacq: a p. 14 Cuu a p. 18 suaa aag ua uc p. 20 puc a
pae 22 GroUp ta e 2006.
me Ea.
//. foreword
extendinG the life of hydrocArBon rEsourcEs Total’s Exploration & Production branch continually pushes oil and gas production to new limits. Drawing on the complete integration of its multidisciplinary expertise, the Group has honed a capacity for innovation that has secured its rank among the frontrunners in the technologies strategic to the future of the energy industry. Total’s Exploration & Production branch is involved in all of the industry’s key technological challenges, namely, extra-heavy crude oil, ultra-deepwater offshore, sour gas, hydrocarbon resources that are deeply buried (highpressure/high-temperature) or difficult to produce because they are in “tight sand” reservoirs. At the same time, the Group
“Innovation will be the main driver of sustainable growth in our production.” is inventing the tools and techniques required to access residual reserves on conventional acreage. Relying on synergies with other Group branches operating in the fields of gas and power, refining and marketing and petrochemicals, the E&P branch proposes technological solutions that cover the complete value chain from production to finished products and/or markets.
04
//. Context
Billions of cuBic mEtErs S A G R U O S
s 1.
Doha, Qatar.
What is sour gas? Sour gas is natural gas that contains not only methane and some long-chain hydrocarbons, but also H2S and/or CO2. Mercaptans, organic sulfur compounds in the form R–S–H, are usually also present. The tubing, pipes and pumps for sour gas must be made of special metal, since H2S, CO2, and mercaptans are corrosive. These compounds must be removed before the gas can be sold.
of GAs wAitinG to be tApped sss Nearly 40% of the world’s gas reserves contain levels of carbon dioxide (CO2) and hydrogen sulfide (H2S) that pose obstacles to development. Overcoming those obstacles is a key challenge for oil companies. World demand for gas has risen at a rate of nearly 3% per year for the past thirty years, making natural gas the fossil energy with the strongest growth. The share of gas in global energy supply expanded from 16% in 1971 to 21% in 2004, and the International Energy Agency forecasts continuing growth, to reach a share of 23% by 2030. In absolute value, gas consumption is thus expected to increase considerably from 2,800 to 4,700 billion cubic meters between 2004 and 2030. This strong development is driven above all by the environmental qualities of natural gas. It is a clean-burning fuel that leaves no heavy residues such as soot or tar, and releases the lowest carbon dioxide emissions of all the fossil fuels. Natural gas is also used to an increasing extent in power generation, where it offers the additional advantage of allowing very high efficiency in both cogeneration and combined-cycle units. Reserves of natural gas are abundant, totaling some 180,000 billion cubic meters worldwide. However, nearly 40% of the fields lying untapped contain concentrations of carbon dioxide (CO2) and hydrogen sulfide (H2S) that pose obstacles to their development. Such sour gas fields are found in Europe, Africa, North and South America and the Far East, but the Middle East and Central Asia hold the largest volumes. Total became a world pioneer in sour gas production with its groundbreaking Lacq gas field development, in France. Since then, the Company has built on its expertise and innovated with techniques to enable the economically viable production of these unconventional resources, in compliance with increasingly tough sales gas specifications and environmental objectives. nnn
1
06
S A G R U O S
s
//. ChAllenGes
A history of ExpErtisE sss Faced with the new challenges of the Lacq gas field, Total invented many production and processing techniques for sour gas that are now used around the world.
Lacq lights the way Total has many years of experience in producing and sweetening sour gas. Two major milestones have been the Lacq field in France and the Ram River project in Alberta, Canada. The aminebased processes developed by Total for separating sour gas still rank among the most efficient solutions currently available.
In the 1950s, with the development of the vast Lacq gas field in France, Total marked a world first by successfully upgrading a very sour gas (16% H2S and 10% CO2) in high temperature and pressure conditions. To cope with the corrosive fluids and sulfur deposits, the Group developed techniques and materials to treat this aggressive gas efficiently and safely. This strong base of know-how has continuously evolved; Total’s technology has made its way around the world to permit the successful development of more than sixty sour gas fields. Flagship projects include Elgin/Franklin (United Kingdom), South Pars and Dorood (Iran), Bongkot (Thailand), Kharyaga (Russia), Sleipner (Norway), and very sour gas reserves in Abu Dhabi. At present, Total is once again pushing back frontiers with cost-effective production methods for ultra-sour gas (over 20% of CO 2 or H2S) and future-looking sweetening processes in preparation for increasingly stringent specifications. In the Group’s hydrocarbon production, the share of gas should reach 35% by 2010. While the cost-effectiveness of technological solutions is a crucial factor for the future of sour gas development, safety for people and the environment is an equally requisite dimension. The Group’s commitment to minimize the environmental impact of its operations is supported by major research activities. For sour gas, the focus is on improving the energy efficiency of sweetening processes, but the teams are also working on breakthrough technologies like the Sprex® (for “Simple PRe-Extraction”) process. Currently in the pre-industrial phase, this process leads to significant savings in both the energy requirements and the cost of treating gas. In line with its comprehensive approach, Total also studies solutions for the management as well as the marketing of sulfur streams and other by-products of the process. For the longer term, additional research programs are under way to explore options for the reinjection and storage of the acid fractions from these gases. nnn
07
Total’s presence in the eld of sour gas
1
2
3
Bongkot South, Thailand. 2. Elgin/Franklin, United Kingdom. 3. Kharyaga, Russia. 1.
//. expertise
A pioneer in thE fiEld of sour gAs sss ta c lacq ga u fac 1951. G g h2s a Co2 cca ga, ucg a cg a a a cag. l a a a, a a acc – ta a u u agg a a cu a g-qua a ga. t u a ua ca c a a Gu’ cgca a a a, u a c u cc c .
10
S A G R U O S
s
//. expertise
lAcQ: A world first sss It took Total a mere few years to develop efficient techniques, notably amine-based sweetening processes, to address the challenges of a high-pressure, high-temperature sour gas reservoir. The Company’s solutions are now used around the world. Total’s first experience with sour gas began in 1951. During an exploration campaign for oil in southwestern France, the Lacq 3 well revealed a significant oil reservoir. The major quantities of hydrocarbons were found at a depth of 3,450 meters — but in gaseous form. The pressure here was so high that a great geyser of gas shot up through the borehole on December 19, 1951: Total’s historic introduction to the Lacq gas giant.
650 bAr of pressUre Shooting out at a pressure of 530 to 670 bar and a temperature of 140°C, the gas initially had to be flared. It took two months to withdraw
“f a” 1957
Lacq: Vital statistics Reservoir Depth: 3,500 m on average Pressure: about 650 bar on discovery, 24 bar today Bottomhole temperature:
140°C Gas composition Hydrocarbons: 74.2% Methane: 69% Ethane: 3% Propane: 0.9% Butane: 0.5% Pentane: 0.2% Hexane and other: 0.6% Acid gases: 24.8% Hydrogen sulfide: 15.3% Mercaptans: 0.2% Carbon dioxide: 9.3% Water: 1%
s a g w a r f o d / m . u c f o s n o i l l i M
f aa eae. de e a ea e
s ee eve
gee ee e ea
Reservoir 650 bar
Reservoir 24 bar
m . u c f o s n o i l l i b n i n o i t c u d o r p s a g e v i t a l u m u C
Record recovery Since 1957 and the start of Lacq gas production, 246 billion cubic meters of gas have been recovered here. Pressure inside the reservoir has dropped from 650 to 24 bar. A great number of seismic surveys and studies were carried out to model the reservoir in 3D,
paving the way to a more detailed understanding of reservoir geometry for optimized siting of production wells. The result: proven recovery of 94%. Lacq has thus also enriched Total’s experience in the production of substantially depleted mature reservoirs.
11
1
Aerial view of the Lacq complex, France. 2. Total has developed a control system that adjusts the activity of reagents in real time to guarantee specified composition of the treated gas. 1.
2
Processing of hydrocarbons from the Lacq field duuza
s ga ra ga
suu c u
s
t cea a
tcca Ca a
lpg ea
sa cack
(bae, ae)
Eee l ab ceae
lacq cu
saza
pee
the drilling assembly and plug the well. When the drill string was pulled out, the engineers discovered an unusual phenomenon – the gas had altered the molecular composition of the steel and caused cracking in all the welded parts.
sUlfide Corrosion CrACKinG The explanation for this phenomenon lies in the composition of sour gas. Containing 10% carbon dioxide (CO2) and 16% hydrogen sulfide (H2S), as in the case of Lacq, the gas causes “sulfide corrosion cracking.” No one at the time knew how to produce sour gas with very high levels of sulfur, and experts considered the Lacq discovery a “write-off.” That was no deterrent for Total. The Group set out fully determined to develop the field, which promised to be a major discovery (over 240 billion cubic meters). Two wells were drilled to appraise the size of the reservoir – one 1,500 m north of the initial well, the other 1,500 m to the south. Both encountered gas, as recorded in 1953. A major research effort then got under way to define the materials and processes needed to develop the gas. In 1955, after two years of work, the Pompey steelworks presented a type of steel that was resistant to H 2S.
12
//. expertise
S A G R U O S
s Parallel research culminated in the choice and optimization pp of amine-based processes (see page 14), the chemical key to the gas sweetening process. Total also worked on the sulfur recovery aspects, and developed Claus-type processes enabling liquid sulfur production with energy recovery. The construction of the gas processing plant got under way at the end of 1955, while appraisal of the field continued. In all, 34 wells were drilled: 32 turned out to be producers.
A GAs GiAnt
Ram River, 35% H2S In 1961, capitalizing on the experience gained at Lacq, Total first exported its knowhow to the Pincher Creek field in Alberta, Canada. In 1972, the Company rose to a new challenge by producing the gas from Alberta’s Ram River field. H2S content: 35%! By successfully sweetening this gas with an amine technology, Total set yet another international precedent, demonstrating that its solutions can be effectively applied to the development of ultra-sour gas resources.
The first production phase began in April 1957, with a processing and production capacity of 1 million cubic meters per day. It included desulfurization, condensate removal, the recovery of sulfur from the H2S, and the refining of the by-products. This phase yielded streams of purified gas along with hydrocarbons that are used by the chemical industry — ethane, propane, butane — and sulfur. Three additional phases were commissioned in July 1958, May 1959, and 1960, boosting processing capacity to more than 20 million cubic meters of gas per day, with an unflinching emphasis on the highest standards of industrial safety. Through Total’s determination and efforts, Lacq grew into a world-class complex. The sulfur from Lacq accounted for 100% of French output, and 8.5% of world supply. In 1960, the field produced 90% of the gas consumed in France. The complex began to take shape as a hub of industry, with a power plant, an aluminum plant, and various plants manufacturing methanol, fertilizers and vinyl chloride, all of whi ch made use of residual gas from the Lacq operations. At its plateau production level in the 1970s, the site was producing 33 million cubic meters of gas a day.
tUrninG A ConstrAint into A leAdinG edGe Although Lacq’s gas production is currently on the decline, the momentum set off by this field is stronger than ever. Developing ever-more efficient sweetening and recovery processes (see page 14), the Group has also exported its know-how internationally, as operator or through licensing. Around the world, more than 60 sour gas fields — including Elgin/Franklin (United Kingdom), South Pars and Dorood (Iran), Sleipner (Norway), and very sour gas reserves in Abu Dhabi — are now being produced using Total processes. Starting with the Lacq field, Total has turned a geological constraint into a technological advantage. nnn
Elgin/Franklin, the challenge of variable composition
Combining record depths with reservoirs in the central part of the record pressures and temperatures UK sector of the North Sea hold (5,500 m burial depth, 1,100 bar vast reserves of gas condensate. The and 190°C), the highly innovative composition of the gas is not quite tandem development of the Elgin the same in the two reservoirs and Franklin fields also constitutes – the CO2 content varies between an exceptional performance 2.4 and 4%, while the H 2S content in sour gas treating. The two can range up to 50 ppm. Total has
succeeded in using a single sweetening unit designed to treat the mix from these two sources, which is a gas with variable composition. Using amine technology (activated MDEA), the sweetening unit directly delivers a gas that meets export-sales specifications, with 1.5% ± 0.2% CO 2 and less than 1 ppm H2S. To absorb the H 2S, the chosen option is moderately activated MDEA, which allows simultaneous, controlled absorption of the CO2 at a rate that varies with the CO2 content of the stream. The concentration of CO2 in the raw stream and in the treated gas is very precisely monitored and the operating parameters of the unit are adjusted accordingly, using a mass transfer model developed by Total. Guaranteeing a gas output in full compliance with export-sales specifications regardless of the inlet composition of the stream, this installation will accept flow rate variations of up to 70%, meaning there is no need for flaring when changes in flow rates and/or composition occur.
Simplified process flow diagram.
14
S A G R U O S
s
//. expertise
continuous innovAtion sss Taking advantage of steady progress in the field of amines, Total has developed efficient and cost-effective solutions for sour gas processing. The success story of innovation is now continuing with the conquest of ultra-sour gas fields, notably via optimized amines and the new Sprex® process. Ever since the first studies for the Lacq gas field in the 1950s, Total has steadily improved its amine-based sweetening processes to hone their efficiency and expand their scope of application. These intensive and sustained R&D efforts have produced a rich and diversified palette of solutions for all types of sour gas streams, consolidating Total’s leadership through the years.
severAl GenerAtions of Amines
South Pars The South Pars gas field in Iran holds slightly sour gas: 2% CO 2 and 0.54% H2S. Since March 2002, this field has been delivering high-quality gas into Iran’s sales network. To avoid hydrate formation and control corrosion in the multiphase pipelines that transport the gas 105 km to shore, a solution of mono-ethylene glycol with MDEA-controlled pH is injected at the production point. The selective sweetening process is carried out onshore, using MDEA. From start-up until now, the treated gas output has exceeded the original project objectives by 10 to 15%.
In 1957, Total’s first sour gas sweetening unit went into operation. It was designed to treat 1 million cubic meters of gas per day, using a process based on diethanolamine (DEA). In contact with the raw gas, the “lean” diethanolamine rapidly reacts with the H 2S and CO2, stripping out the acid compounds. The “loaded” amine is regenerated in a reboiler and then used again. This process was improved over the years to reduce costs and energy consumption, and boost sweetening efficiency. In 1978, Total achieved another technological milestone that opened the era of selective sweetening using methyl diethanolamine (MDEA). This process was applied for the first time at the Chémery u nit, then integrated into several Lacq units in 1980. MDEA has slow CO2 absorption kinetics. It thus captures significant amounts of H2S only, with practically no change in CO2 levels. This property makes MDEA a very attractive candidate for some North Sea and Middle East fields. In addition, its regeneration requires less energy than for DEA, adding up to substantial savings in the gas treating cycle. In 1990, the studies conducted by the Group paved the way for another major step: Total extended its portfolio with a process for “made-tomeasure” sweetening. In this new-generation process, first used on the Lacq gas field, the MDEA is activated using a secondary amine that accelerates the reaction of the CO2 with the aqueous solvent. The speed of reaction is modulated by using different types of activators, in different concentrations. The process thus allows either complete or specifically controlled removal of CO2 (see process flow diagram, page 15 ). These technological achievements have met with commercial success worldwide. Robust, reliable and efficient, the processes have found numerous international applications: as early as 1961 for DEA, and sin ce 1987 and 1996 for MDEA and activated MDEA respectively. Between 1957 and 2005, some 70 projects in Canada, India, Iran, Nigeria, Norway,
15
On Elgin / Franklin, sour gas is sweetened by contact with the amine solution in an absorption column.
Qatar, Russia, the United Kingdom and elsewhere chose Total’s amine technologies to treat their raw sour gas, either entrusting the operations to the Group or applying Total’s technologies under license.
hybrid solvent teChnoloGy The R&D teams at Total are now working on new projects for amines offering optimized technological and economic performance. Particular attention is being focused on hybrid solvents (i.e., adding a physical solvent to the amine, a chemical solvent) and on mixtures of different chemical solvents. These processes are more effective at separating organic sulfur compounds (mercaptans), COS and CS2, and solvent regeneration requires less energy. In addition, regeneration can be carried out under pressure – a major advantage in light of new production scenarios based on the re-injection of compressed acid gases into geological reservoirs, which may or may not be depleted. Hybrid solvent processes would fit perfectly into such a residual acid gas injection chain, improving processing performance while reducing overall energy consumption. These solutions are also promising for the removal of mercaptans from sour gas, which at present requires large amounts of solvent.
pp
Total amine processes: a history of progress • DEA : diethanolamine (HN – (CH2-CH2-OH)2), a secondary amine. The first generation of solvents used by the Group. • MDEA : methyl diethanolamine (H3C–N (CH2 –CH2 –OH)2), a tertiary amine. This second generation of amines was
developed by Total’s R&D teams. • Activated MDEA : in this latest generation process first used on the Lacq gas field in 1990, the MDEA is activated with a secondary amine that accelerates the reaction of the CO2 with the aqueous solvent. The speed
of reaction can be modulated by the choice of the activator. This process thus permits either complex or controlled removal of CO2, for “made-to-measure” sweetening solutions.
16
//. expertise
S A G R U O S
s Total R & D systematically screens potential molecules and then pp tests the efficiency of each formulation using a pressure pilot at Lacq. This new type of process can supplement existing solutions to remove compounds that resist the amines, thereby reducing overall energy consumption. With its mastery of the entire gas treating chain, Total is fully equipped to move rapidly from tests to an industrial solution.
sprex®, A teChnoloGiCAl breAKthroUGh
Extending Sprex® to CO2 The Sprex® process was initially developed to separate H2S. An improved version is now ready for the treating of gas with high CO2 levels. In this process, named Sprex® CO2, a temperature of about -60° to -70°C must be attained, depending on the target specification. That requires preliminary dehydration of the gas, to avoid hydrate formation in the Sprex® column. Sprex® CO2 is a cost-effective alternative to conventional processes based on solvents or semi-permeable membranes for treating gas with high CO2 concentrations.
Established technologies for sweetening raw sour gas are destined to evolve, however, given the limited size and the saturation of the market for sulfur reclaimed from the residual H 2S. Moreover, environmental constraints now limit discharge of CO2 and SO2 to the atmosphere. For this new challenge, Total collaborated with the French Petroleum Institute, IFP, to develop a new process called Sprex® primarily targeting fields in the Middle East that have not been produced for lack of economically viable solutions. With Sprex®, the scope of application of the more conventional amine-based chemical processes can be extended to gas with very high H 2S concentrations. Sprex®, short for “Simple PRe-Extraction”, is used early in the sweetening chain to separate H2S by cryogenic distillation. The acid gas fraction is extracted in liquid form, at high pressure (50 to 70 bar). This liquid is rich in H2S and contains CO2, the heavier hydrocarbons, and water; it can easily be pumped into a geological reservoir. The pre-sweetened gas from the Sprex® unit is then treated in a conventional amine unit of small size. Although the process requires two steps, this technology is less costly and especially less energy-intensive than equivalent treating using amine technology alone, essentially because of the savings on the compression of the acid gas.
Sprex® operating principle Sales gas
> 20% H2S Raw sour gas
10-12% H2S s®
Pretreated gas
Ca ag
(e.g., amine scrubbing)
Liquid H2S
Residual acid gas
Re-injection
17
Sprex® process flow diagram Condenser
- 30°C Raw gas in Lowtemperature separation Reflux (H2O rectif) Distillation Reboiler (HC stripping) Purified gas out
Scrubber 60-70°C
Liquid H2S
H2O
In the period from April 2005 to July 2006, the Sprex ® process was validated at the Lacq plant in a unit with a treating capacity of 70,000 cubic meters of raw gas per day. The feed stream was a water-saturated gas containing 18 to 40% H 2S. The experience gained by running this industrial pilot has allowed Total to demonstrate the robust qualities of the Sprex® process, which has now been fully integrated into the Group’s portfolio of sweetening solutions. nnn
License co-management with IFP Total has entrusted the French Petroleum Institute (IFP) with the management and marketing of its gas sweetening processes. IFP’s wholly-owned subsidiary Prosernat designs the sweetening units.
Sprex®: the pilot unit at Lacq.
18
S A G R U O S
//. expertise
sUstAinAble mAnAGement of rEsiduAl products
s
sss Total is developing specific techniques to make the development of sour resources as safe as possible for the environment. Injection is an option that avoids sulfur production and reduces emissions of CO 2. Sour gas processes generate emissions that have strong concentrations of H2S — a lethal gas in even minimal doses — and that may also contain CO2, entailing harmful effects on the environment. The safe and reliable management of these so-called residual gases is a priority focus of the Group’s Research & Development efforts.
solUtions for sUlfUr
GTL and CO2 Produced CO2 can be economically reclaimed in a Gas-to-Liquids (GTL) conversion reaction. This option is being explored through research into the Fischer-Tropsch GTL process, which produces syngas then converts it into liquid hydrocarbons. The presence of CO2 in the feedgas for the syngas reactor improves the carbon efficiency of the GTL conversion.
H2S can be converted to sulfur using Total proprietary processes in Claus units. In the first phase, part of the H2S is converted to SO 2 in a thermal reaction: 2H2S + 3O2 ➝ 2SO 2 + 2H 2O. The SO2 is then contacted with the remaining part of H2S for a Claus reaction yielding sulfur: 2H2S + SO2 ➝ 3/2 S2 + 2H 2O. With this option, sufficient energy to power the gas sweetening units can generally be recovered provided the H2S/CO2 ratio is high enough. The Group has also developed Sulfreen, selective amine and other processes for treating residual gases from sulfur plants, and possesses know-how in the area of sulfur conditioning systems, notably for degassing liquid sulfur with Aquisulf technology. In other words, Total can boast end-to-end mastery of the chain: production, handling, storage, and sale. The saturation of the sulfur market — a situation that is likely to last — is prompting the need for new solutions for the storage of sulfur or H2S. One option considered promising by many operators is injecting residual acid gases directly into depleted reservoirs. This can be facilitated by using the Sprex® process, as it enables the separation of H 2S under high pressure. Implementing this solution requires complete control of corrosion and all other aspects related to the extreme toxicity of H 2S. The risks and uncertainties involved in storing H2S in geological reservoirs must also be fully mastered. This is one of the major challenges facing the Group as it pursues research in this extremely complex field. Residual acid gases can also be used to enhance oil recovery (EOR), but to avoid the risk of cycling these gases into the producing wells, thorough knowledge of the reservoir and mastery of material-flow modeling are imperative.
solUtions for Co2 Although the residual CO2 from treating sour gas is less hazardous than the H2S, it nonetheless contributes to climate change. The Group’s objective is thus to release as little of it as possible into the atmosphere. Total is therefore studying options such as CO2 storage in depleted
19
The various types of geological storage
1
co2 ae a eee a e.
2
co2 ae a ae aqe.
3
co2 ae a e Eor.
reservoirs, deep saline aquifers, and coalbeds, but also the use of CO 2 for enhanced oil recovery (EOR). In 2001, Total E&P teamed up with various research institutes and partners in academia and industry to undertake an R&D program dedicated to CO2 capture and storage. The program gives the Group a role in a number of national and international initiatives that draw on theoretical and experimental research, industrial pilot installations, and lessons learned from ongoing projects. For example, Total is a member of CO2 ReMoVe, a consortium uniting different industries and research organizations to foster the development of projects for the geological storage of CO2 in Europe and neighboring countries. The Group is also a member of the ENCAP (ENhanced CAPture) working group, coordinated by the Swedish energy concern and power producer, Vattenfall. ENCAP focuses on the development of CO2 capture processes for coal-, natural gas- and oil-fired power generation systems. The Group also supports Picoref (Piégeage du CO 2 dans les Réservoirs en France) which is preparing industrial demonstrations of CO2 injection in France, notably in hydrocarbon reservoirs and salt aquifers around Paris. More concretely, Total is participating in the project on the Sleipner field, where CO2 has been injected into an aquifer since 1996. The Group is also a partner in the CO2 injection project in the Statoil-operated SnØhvit field (Berens Sea). In this project, the CO 2 is extracted onshore in an LNG plant, then piped back out to sea and injected via subsea wells into the saline formations of the Tubåen sandstone, at a depth of 2,600 m. On Canada’s Weyburn oil field, Total is a partner in yet another R&D project centered on the first industrial-scale application of CO2 capture combined with enhanced oil recovery.In 2005, the Group launched the study phase in preparation for the construction of a pilot oxyfuel combustion installation for CO2 capture and storage in the depleted reservoir of the Lacq basin in France. nnn
4
co2 ae abe eae eae eve.
Crystallizing sulfur in the reservoir An alternative to geological storage of H2S is to produce solid sulfur not in surface facilities, but in depleted hydrocarbon reservoirs that contained H2S. This principle involves burning the H2S or sulfur to obtain SO2 that can be reinjected into the reservoir. In a Claus reaction, the contact of this fluid with the native H2S in the reservoir would yield water and sulfur. If it proves feasible, this method will offer the advantage of a long-term solution to the problem posed by H2S, since solid sulfur is perfectly stable. This option could thus be applied in appropriate depleted reservoirs near producing sour gas fields.
20
S A G R U O S
s
//. expertise
prodUCtion sAfEty sss Toxic, corrosive and sometimes flammable, sour gas raises critical production safety issues. Using purpose-designed materials, dense arrays of sensors and leading-edge risk modeling, Total can produce these challenging resources without compromising on safety. Ensuring the safety of facilities and operations is a core responsibility for an industrial player like Total. This imperative requires specific measures when producing and processing hazardous fluids such as sour and acid gases.
Gas detectors.
prevention And AntiCipAtion Two pillars of Total’s safety policy are risk assessment and anticipation, aimed at preventing accidents and minimizing the consequences of any that do occur. In practice, that translates into strict safety procedures, regular accident simulations and safety drills conducted at all Total-operated sites. Accident scenarios undergo quantitative risk analyses in which 2D and 3D tools are used to fine-tune simulations of pollutant dispersion patterns and delineate hazard zones. Research is also ongoing to improve dense-phase dynamic simulation models.
A global challenge for the Group Worldwide, the Group has operations at more than 500 sites that fall within the scope of the European Union’s Seveso Directive on establishments where dangerous substances are present. In this context, the policy pursued by Total is supported by assessments of its safety management systems by independent and globally recognized auditors. By late 2006, over 70% of the Group’s worldwide facilities will have been assessed. In late 2004, Total also instituted a standard method for risk assessment to be applied across all of its global activities. This method is designed to harmonize the assessment criteria used in the different sectors of activity, and to
provide more detailed data on the risks related to its facilities. Managing any potential crises or emergencies demands flawless coordination among all the entities involved, coupled with a capacity for prompt mobilization of a multidisciplinary network assembling the relevant skills and expertise. To ensure the solidity and responsiveness of its crisis management organization, Total has established three levels of response: the “Local level” (site or subsidiary) to manage the situation in the field; the “Branch level” to mobilize a multidisciplinary team; and the “Corporate level,” to take decisions beyond the immediate term and ensure the necessary oversight.
2
1
3 1. and 2. The
Corrosion Control Total has implemented alloys specifically adapted to sour gas flows since the late 1950s, with the development of the Lacq field. The more aggressive fluids in as-yet undeveloped fields pose new challenges in terms of both tubing and pumps. For example, future development schemes call for the re-injection of the residual acid gases — fluids with high concentrations of H2S or CO2 — and at this point their behavior under high pressure is less well known. A lab study by the Total R & D group working on gases with high H2S levels has measured the corrosiveness of these water-undersaturated gases in su percritical conditions. Having worked on many sour gas fields for several decades, Total has successfully expanded its expertise to include dense-phase sour gas fluid dynamics.
reAl-time monitorinG to GUArAntee sAfety Given the high toxicity of H2S, a massive leak of sour gas would have disastrous consequences for people in the vicinity, both at the site and in the surrounding communities. It is thus crucial to be able to detect any anomaly, even the slightest leak, because the alert must be given immediately. A pilot site for managing this type of risk is Lacq, which has about a thousand sensors controlled in real time with monitoring of safety systems from the single control room. Total has begun to research new ways of combining measurements to allow an automatic safekeeping of the installations, for faster and more reliable prevention and containment. nnn
control room at Lacq, France. 3. The Lacq site is in the vanguard of risk management know-how.
22
S A G R U O S
s
//. GroUp
totAl worldwidE in 2006 sss Present in more than 130 countries, Total is one of the most dynamic players in the global oil and gas industry, with a number of truly major technological and economic achievements to its credit. ACtivities in every seGment of the oil And GAs seCtor
Exploration & Production in figures – 2006 Workforce: 13,624 employees (31 December 2006). Investments: e9 billion. Oil and gas production: 2.36 Mboe/d. Proven oil and gas reserves: 11.12 Bboe. Operations in more than 40 countries. Leading oil and gas producer in Africa. Second-largest hydrocarbon producer in the Middle East. Partner in 5 gas liquefaction plants accounting for nearly 40% of global LNG production.
In addition to its prominent positions in oil and gas exploration and production, gas and power, trading and transmission, and refining and marketing, Total is a key player in the Chemicals sector. In 2006, the Group produced a total of 2.36 million barrels of oil equivalent per day (mboe/d). Its future growth is underpinned by proven reserves of 11.12 billion barrels of oil equivalent and a portfolio of assets spanning the key oil and gas provinces of the globe. Leader of the European refining and marketing segment, Total holds interests in 27 refineries and is operator on 13 of them. The Group’s retail network numbers more than 16,500 service stations, mainly in Europe and Africa. In the Chemicals sector, Total is one of the world’s foremost integrated manufacturers, with leading positions in each of its main markets in Europe: Petrochemicals, Fertilizers and Specialty Chemicals.
At the forefront of explorAtion & prodUCtion teChnoloGy Total can boast of being one of the most dynamic and successful players in the global oil industry. Sustaining its momentum through an active exploration program and state-of-the-art research capabilities and expertise, the Group operates in a variety of geographical and technical contexts and pursues the strategic objective of extracting maximum value from hydrocarbon resources sustainably, with full regard for human safety and environmental protection. While seeking to optimize ultimate conventional resources and extend the life of mature fields, the Group is also a leading exponent of the innovative technologies required to secure access to future resources. The many large-scale projects to the Group’s credit have amply demonstrated its capacity to master the technological and economic challenges of producing large fields in frontier domains, including high-pressure/high-temperature fields, extra-heavy oils, production in the deep and ultra-deep offshore, multiphase transport of effluents, and more. nnn
23
The 30 giant projects for sustained growth
Geographic and technical diversification
Forecast growth in production
Proven reserves: more than 12 years
Proven and probable reserves: more than 20 years
Aa n n Aea n Aa n Ee n re e n
Ea-eav n dee/a-ee ae n oe q n lng n oe a je n
Ea-eav n dee/a-ee ae n oe q n lng n oe a je n
* Estimates based on a price of US$60/b i n 2007 and US$40/b from 2008.
p c: f. gz/héèe, p, dr/ ta, caa, m. d a m. re ta – igac: ié, ta – – pg: ce – © ta – ma 2007. dg-uc:
//. the Know-how series E aea eee ee e e ab ee
Coming soon
TOTAL S.A. Capital stock: 6,062,232,950 euros - 542 051180 RCS Nanterre Eploato & Poto - Pas 2, place de la Coupole - La Défense 6 - 92400 Courbevoie - France Tel. 33 (0)1 47 44 45 46 Eploato & Poto - Pa Avenue Larribeau - 64018 Pau - France Tel. 33 (0)5 59 83 40 00 www.total.om
