Occidental Petroleum Corporation (Occidental) discovered the Porvenir field in 1978 and constructed the Porvenir Gas Plant in the early 1980s to separate condensate and re-inject gas into the field. The field and the gas plant located in Chuquisaca Department, Bolivia, were developed in partnership with Yacimientos Petroliferos Fiscales Bolivianos (YPFB), the Bolivia National Oil Company. A 40-year concession agreement expired in May 2017. Porvenir field production stopped in 2006, due to high water cut and sand migration problems. In 1996, Vintage Petroleum Boliviana Ltd (VPB), a wholly-owned subsidiary of Occidental, constructed a 10-inch pipeline to Porvenir Gas Plant, which processed and stabilized gas and condensate from the adjacent Nupuco and Chaco Sur fields until May 2017. Upon cessation of the field production and in compliance with the Bolivian Hydrocarbon Law 3058 and operation agreement, VPB undertook the Porvenir Gas Plant Decommissioning and Rehabilitation activities with the approval of the Ministry of Hydrocarbons and Ministry of Environment and Water in August 2017. The objective of this paper is to share the key process safety, process risk, environmental, and social responsibility considerations associated with the field and gas plant abandonment and rehabilitation. The paper also highlights project management and technical and non-technical risk management strategies that VPB adopted to achieve successful closure. The project's engagement with all the stakeholders— government entities, national oil company, communities, employees, contractors, and others—exemplifies Occidental's and VPB's fundamental approach and core values as Partner of Choice. VPB became the first oil and gas company in Bolivia to undertake such an endeavor in the recent times.

Repsol Exploración Perú (Repsol) develops its operations in accordance with its integrated policy and incorporates the criteria of safety, health and environment in all activities. In compliance with this policy, Repsol develops environmental management strategies (EMA) for its projects. The EMA prepared for the Environmental Impact Study of the Sagari Field Development Project - Block 57 is based on the mitigation hierarchy. This hierarchy proposes measures to avoid, mitigate, restore or compensate for the negative challenges identified for the project in its planning, construction, operation and abandonment stages. This project includes the completion of a well in Sagari BX, the drilling and completion of 2 development wells in Sagari AX, the drilling of an injector well, and the construction and operation of an 18.7 km conduit that joins the new facilities of production and connections to the affected facilities in Kinteroni. The project is located in an area of high biodiversity and overlaps the buffer zones of the Machiguenga Communal Reserve and Otishi National Park. This document has two objectives: The first is to show the mitigation measures incorporated into the project, which meet the highest industry standards. The second objective is to serve as a guide and reference during the planning of similar hydrocarbon exploration and development projects in the Amazon.

Mitigating greenhouse gas emissions and meeting the aim of the Paris Agreement requires worldwide action from all sectors of society. As a major emitter of energy-related CO2, the transport sector will require a transformation over the course of this century. Before, during and after the adoption of the Paris Agreement, IPIECA issued a series of publications, held dedicated workshops and hosted a number of topic-specific side events at UNFCCC COPs (Conference of Parties) to convene experts from industry, academia, think tanks and other stakeholders to produce a perspective on the potential pathways toward a low-emission future and the role of the oil and gas sector as an enabler. Building on this approach, IPIECA worked with experts within the sector and drawing upon data and literature from the IEA and other bodies to produce in-depth low-emission pathways for transport. IPIECA identified a wide range of technologies that will be necessary for transport sub-sectors (light-duty and heavy-duty road vehicles, aviation and maritime) to evolve to a low-emissions future. Continuing improvements in the efficiency of the internal combustion engines coupled with hybridization and optimized vehicle/vessel designs will provide significant GHG emission reductions. Electric vehicles are key for the light-duty sector, although the full life cycle of battery manufacture, utilization and disposal as well the sustainability of electricity generation source is particularly important if valid comparisons are to be made with internal combustion engines. More advanced biofuels, synthetic fuels, ‘e-fuels’ and hydrogen could also be used as a power source to improve emissions. And, there is a role for carbon capture and storage (CCS) in the production of hydrogen. Transport modes such as heavy-duty vehicles, aviation and commercial shipping need a significantly high energy density. Here electrification will present more of a challenge and there is the opportunity for use of sustainably sourced biomass as an alternative. This paper will lay out the IPIECA view on how the oil and gas industry can be part of the solution in meeting both the challenges of the Paris Agreement and the UN Sustainable Development Goals. It examines in detail potential pathways for the transformation of the transport sector and provides a perspective on the technologies and other key enablers of a low-emissions transport future.

There is a global trend towards the application of risk based assessment (RBA) techniques for assessing and managing environmental risks and considering the potential impacts from discharges of produced water. One of the benefits of RBA is the absence of generic end-of-pipe limits for individual produced water components. Instead, it allows for flexibility to evaluate environmental risks and potential impacts of site-specific discharges on a case-by-case basis. Several global oil and gas operators have developed in-house approaches, guidelines and principles for evaluating these risks for communication to agencies and the public and for decision making. As such, a range of risk endpoints is being applied, each of them based on specific assumptions, input parameters with varying levels of empirical data requirements, and conservatism. This situation hampers straightforward comparison across companies and regulatory frameworks. The International Association of Oil and Gas Producers (IOGP) has recognized a need for alignment to support more consistent application and communication of RBA concepts. Therefore, a new IOGP project was sponsored, including formation of a Task Force to define industry good practice for RBA approaches, based on an inventory of methods currently used by member companies together with a review of existing regulatory approaches around the world. Tools have been catalogued and the strengths and weaknesses of the underlying risk principles have been analysed along with the protection goals they support. Two main principles were identified; Uncertainty-implicit and uncertainty-explicit approaches, each with their own application areas. The second phase of the project focused on the development of consensus industry guidance including a common tiered framework for RBA. The main objective of this work is to achieve harmonization in the way operators execute RBA for offshore produced water discharges as this will likely enhance broader understanding and acceptance of RBA techniques internationally. This paper will provide a summary of the inventory of RBA methods and tools collected by the Task Force and will present the main elements of the proposed common RBA framework for produced water discharges. This will include recommendations e.g. on how to characterize produced water composition, how to define appropriate mixing zones, and what data is needed to decide whether risk can be considered adequately controlled.

The International Association of Oil and Gas Producers (IOGP) is a global forum in which member companies identify and share best practices to achieve improvements in many areas including upstream process safety. The IOGP Safety Committee has undertaken a multi-year strategic project to focus on fatality prevention, known as Project Safira, which addresses transportation safety, personal safety and process safety. This paper presents data analysis work conducted on process safety and the associated learnings. In 2010, the IOGP started a pilot project to collect upstream process safety event (PSE) data in alignment with the upstream and downstream reporting criteria. Since 2014, an annual quality control and validation review of process safety event data, reported by IOGP member companies, has been undertaken by a group of process safety engineers and data reporting experts. This group has, over a period of years, developed a list of point of releases and refined a set of key words based on the threat lines in a generic PSE bow tie. With five years of PSE data reported by IOGP Member companies, this paper presents the findings from the data analysis process as well as insights and learnings. Submitted Tier 1 narrative descriptions have been analyzed annually, as well as collectively, to determine trends in points of release, category key words, causal factors and chronological patterns in fatal incidents. The results have shown differences in causes related to events with fatal or environmental outcomes. This provides the basis for a standardized industry approach in prevention strategies to eliminate process safety fatal incidents. Having the largest database of upstream process safety performance and fatality data enables analysis of upstream PSE trends and learning that is not possible in individual companies. IOGP is in a unique industry position to encourage international upstream industry collaboration and sharing of industry best practices to prevent process safety incidents, and their potential impact on life, the environment and assets loss.

Occidental de Colombia, LLC has been developing and operating the Caño Limon field, located at the Arauca department in Colombia, throughout the last three decades, drilling more than 600 wells. Taking into account that the oil industry is seen as an invasive activity, and, based on the biodiversity conditions and conservation of this area where the field is located, environmental good practices were incorporated in a positive way. Results of these practices are seen on an increase in the ecosystem structure, revegetalization areas and restoration within production facilities, with a 54.7% increase between 1993 and 2012 for the Tropical Rainforest (ShT, as per Spanish acronym). Available habitats have been generated while a very important decrease in cropping areas has been noticed (98.02%) because of the conservation systems that have been implemented in the field. Meanwhile, an important reduction of floodplain ecosystem because of the increase in rainforest areas, and the successive processes of regeneration of these ones for the last 19 years, allows that the Caño Limon area acted as a refuge for the third part of the regional fauna. These conditions aimed at environmental sustainability, and ensuring that the ecosystem services of the area are maintained. These activities have only been achieved with a clear policy and actions that have been directed by the company in favor of a synergy between industry and environment. As a consequence of these strategies, the field of operations is another element within the environmental components that integrate the landscape.

Monitoring, understanding, and communicating the impact of offshore oil and gas exploration and production (E&P) activities on marine mammal (MM) biodiversity can be challenging. Here, we share methods, results, and experiences accumulated during seven years of monitoring MM and underwater sound in a mature E&P activity area in the North-East Atlantic. We collected data on the distribution and behaviour of MM, their prey and changes associated with impulsive (e.g., seismic) and continuous (e.g., platform) sound generated by E&P operations. A program was created as an incentive for offshore staff to report systematically incidental MM sightings. Underwater acoustic recorders were placed around producing facilities and across a 3D seismic survey area before, during and after acquisition. A 2 nd Generation Environmental Sample Processor (ESP) was deployed to collect and analyse environmental DNA (eDNA) from seawater to identify MM species and their potential prey. Monitoring data were shared with relevant stakeholders through publications in scientific journals, presentations at conferences and meetings, or through social media. Our data provided evidence of MM activity in the E&P activity area year-round. A total of eight species were sighted from platforms and vessels; harbour porpoise being the most common MM. Harbour porpoises were recorded as being within 800m of the platform three times more often than at stations further away. Near installations, acoustic data showed porpoises actively searched for prey whilst eDNA confirmed the presence of prey species - validating a strong reef-effect. Decrease in porpoise echolocation to 8-12 km from an active seismic vessel, is suggestive of a temporary displacement of animals in the corresponding area. There was no large scale or long-term displacement as harbour porpoises were detected again in the area few hours after airgun operations ended. The results indicate that despite elevated sound level in the E&P area, porpoise distribution appears to be linked to higher availability of prey around the artificial reef created by subsea O&G structures. The monitoring efforts generate valuable scientific knowledge, which form a sound basis to support management and regulation of E&P activities in Denmark. Additionally, several simultaneous tangible benefits resulted from the study such as staff awareness of biodiversity and increased stakeholder interactions. Results and methodologies may be used by HSE practitioners and O&G project managers to assess the potential impact of sound generated by O&G industry on marine mammals. Our success illustrates the value of long-term monitoring and should inspire and support HSE practitioners in their future environmental monitoring initiatives.

The objective of this paper is to share our lessons learned from 10 years of carbon emission reduction efforts and reporting. This includes emissions from our direct operations and value chain and more recent efforts to measure, reduce, and verify emissions from our products and services. We provide a holistic view of our journey, including successes and challenges. Our data collection efforts have evolved over the years as we’ve endeavored to obtain verifiable information across a complex global organization. We’ll describe how to select a scope and boundary, develop a reporting threshold, present data to improve visibility and drive behaviors, enhance reporting processes, obtain desired precision and accuracy, and ensure appropriate external verification. We also discuss considerations involved with external reporting through company reports, to CDP 1 , and to investor sustainability surveys. Finally, we review how to identify improvement projects, establish the business case, examine funding mechanisms, organize an internal strategy team and leverage internal and external collaboration forums. We’ll demonstrate how our 10-year track record of consistent progress enabled our bold commitment, to reduce our combined Scope 1 and 2 carbon equivalent emissions 50% by 2030 and to achieve net-zero by 2050. Our carbon reduction pathways include: Facility Operational Improvements Identifying opportunities using energy treasure hunts, audits, and Lean Six Sigma/kaizen events, installing smart meters, variable frequency drives, automation, additive and intelligent manufacturing, and lower emission refrigerants. Building Construction, Renovation, and Retrofits Using sustainable building standards and energy efficient equipment including LED lighting, building automation systems, heating/cooling equipment and building envelope. Transportation in Company Vehicles Implementing a vehicle idling policy, optimizing scheduling and logistics, and enabling use of electric vehicles. Renewable Energy Sourcing Incorporating an increased percentage of renewables in utility contracts and the increased use of onsite power generation through rooftop solar and other opportunities. Tool and Equipment Redesign Reducing energy consumption as identified by the systematic use of life cycle assessment to quantify emissions of our products and services. In addition to tool and equipment redesign, we are working to reduce other elements of our Scope 3 emissions through employee commuting solutions and evaluating and adjusting modes of transport through the Eco Mode process. We believe the continuity of experience across a full ten-year period provides a broad array of learnings, which can help others at various stages of their journey. As of mid-June 2019, we were the first and only energy service and equipment company to have made a carbon reduction commitment that aligns with the Paris Climate Accord, demonstrating that we will do our part to limit global warming to 1.5 degrees Celsius.

This paper explores the collective actions operators and oilfield services companies can take with local communities to promote long-term operational stability using a case study from a mature oilfield in the Latin American region. When the current operator became the license holder, it also took ownership of all community-facing responsibilities. In the years that followed, the company signed a long-term commercial agreement to co-manage three blocks with specific project management responsibilities for the preparation of the field development plan, drilling campaigns, and facilities construction. Following social due diligence during the business development phase, the company prioritized allocating time for analysis and planning to establish its own community liaison team. The priority was to align responsibilities and interfaces with the operator, while establishing structured long-term plans for community engagement, local content, and social investment. With an operational footprint covering over 1200 km 2 and over 80 indigenous and settler communities with a diversity of backgrounds, operational activities had to be managed sensitively. In creating its own community liaison team, with limited responsibilities for direct interface with communities, the company focused on implementing fundamental and risk-based controls from its social management system. The company focused on building a culture of respect for communities, mapping areas of potential sensitivity, managing tier 2 contractors’ social and environmental performance, optimizing local content by prioritizing local supplier participation and development and ensuring worker hiring processes are perceived as fair and transparent, and implementing a strategic social investment program along with the operator. Collaboration between the operator and company can lead to improved community well-being, operational stability and improved business performance. The paper highlights the importance of social performance integration across the oil and gas industry value-chain. It provides insights into the practical application of the 2018 IPIECA community liaison officers’ team building and management guidance from a company perspective.

Global warming is one of the most serious environmental, social and economic threats currently facing the planet, so many companies and organizations have generated a strategic approach to combat it. One of the most efficient strategies is the reduction of energy consumption, which not only positively affects the reduction of fuel consumption, but also shows improvements in both financial and technological efficiency. This project allowed to create an analysis methodology applicable in the oil and gas industry, in whose process of analysis, important alternatives for optimization of energy consumption are detected, which contribute to the Greenhouse Gas Emission balance (GHG), a fundamental theme of Sustainability Worldwide. This methodology was applied in the field of higher production of hydrocarbons currently in Colombia, whose energy consumption is significant at the national level. The methodology included activities to measure energy consumption per well, coupled with a rigorous financial analysis that allowed the evaluation and selection of candidate wells for different optimization actions. As a result, technically applicable actions were obtained for the reduction of energy consumption, which were classified under an analysis of expected net present value and investment efficiency.

The expectation of policymakers and stakeholders is that the oil and gas industry will continually improve its operational performance by reducing fugitive emissions of methane along the value chain. IPIECA has undertaken numerous wide-ranging activities on methane such as: holding workshops; publishing a factsheet on Exploring methane emissions ; and developing a Methane glossary to help educate industry and stakeholders in a common terminology. There is a huge number of initiatives and studies underway in this topic area and it is difficult for any organization to keep track. Using commercial software, IPIECA has collected information from hundreds of methane studies and initiatives and built an interactive map that displays this information in an easily understood form and allows the user to undertake a gap analysis against a range of parameters. The methane mapping tool provides an analysis of the numerous methane initiatives, planned, underway or completed. In scope are workshops, published articles, assessments, data or any activity related to detection, measurement and reduction of methane that is publicly available or provided by relevant parties. We included initiatives from: academic institutions with specific methane projects; industry bodies; government research support programmes; international institutions; and NGOs. Information was collected and sorted by data and performance, methane science, and technical application and good practice and an analysis of gaps was conducted for each of the themes explored. This paper provides a novel approach through an interactive software map capturing a wide range of technical information from numerous academic, industry and other sources covering methane studies and initiatives, technology use and development, data analysis and verification, geography. It allows for a new type of interrogation by the user to produce a dedicated gap analysis for further focussed work, or to categorise and signpost to existing studies.

Greenhouse gas (GHG) emissions contribute to climate change and can negatively affect the reputation of petroleum companies, being a challenge for their operation. This study evaluates three options for reducing GHG emissions in the Llanito field, located in Santander, Colombia. The first is based on curbing gas flaring, by building natural gas pipelines and promoting the use of the gas. The second considers the installation of a steam recovery unit in a flash tank. The third comprises the CO 2 capture and subsequent injection in the hydrocarbon reservoir (CCS), aiming at enhancing oil recovery (EOR). Findings show that, in the first case, emission decreased from 21.05 gCO 2 /bbl to 16.71 gCO 2 /bbl. The second case lowered emission intensity by 3.24 gCO 2 /bbl, and in the third case, emission intensity decreased from 25.01 gCO 2 /bbl to 17.58 gCO 2 /bbl. The implementation of the three cases together (case I + case II + case II) has a potential to reduce the emission intensity by 19.01 gCO 2 /bbl.

To mitigate climate change, the execution of large-scale projects is necessary. The 20-year projected scenarios show that all actions that are technically viable are required, including some that have to be executed with significant financial assistance from the Government. Global warming generated by the increase in Greenhouse Gases (GHG) is one of the most serious environmental, social and economic threats currently facing the planet, therefore it is essential that each individual, organization or country, is involved in a broader conversation about the importance of planning and taking a strategic approach to combat it. This research, accompanied by analytical work, allowed documenting one of the possibilities of capturing GHG, which could be synergized with an important project such as the development of Colombia's source rock hydrocarbon resources. An economically viable option that can continue its planing stage and be included in the technical options that can be adopted in the future, not only because of the reduction in emissions that it generates, at the same time, the promise of interesting value it can generate a great impact.

Detection and quantification of gas leakage by infrared technology This article aim to present the technology for detection and quantification of fugitive gas emissions in deep offshore activities of TOTAL E&P Angola (hereafter mentioned as "Company"). Company has been operating in Angola for more than 60 years, totally committed to the environmental sustainability through full compliance to the local regulation, Company standards, and best oilfield environmental practices. Fugitive emissions represent a general set of emission from industrial sources that cannot be connected through controlled means to a definitive emission point. These normally and relatively small and hard-to- detect emissions from valve packing, pump seal, compressor seals and piping connections occur as part of normal industrial operations. They are characterized by a diffused release of VOC (Volatile Organic Compounds: methane, ethane, methanol, etc) or other pollutants into the atmosphere. Methane’s global warming potential is higher than carbon dioxide. Methane emissions in Company’s operated scope stood at 2.3 Mt CO2-eq in 2015 and nearly half or 1.1 Mt CO2-eq were specifically related to gas production. In all, they account for less than 0.5% of Company’s marketed operated production; therefore improving methane measurement and mitigating these emissions are part of climate change strategy of the Company. Reducing oil and gas methane emissions is an essential, low-cost strategy for slowing the accelerated pace of today’s Global Warming. It is a major opportunity for climate progress that cannot be missed. This is why all efforts were centered to join the Climate and Clean air Coalition (CCAC) Oil & Gas Methane Partnership, important step to understand the scope of the company methane emissions. The CCAC Partnership provides companies with a credible mechanism to systematically address their methane emissions and demonstrate this systematic approach to stakeholders.

This work provides options to reduce the number of oil pipeline adverse events caused by human actions, poor performance of facilities, accidents, emergencies, and external events. These alternatives provide useful tools to decision makers to prevent such events and improve the security, integrity and resilience of existing oil and gas transportation infrastructure. This research implements an in-house visualization software that is based on Structured Query Language (SQL), Geographic Information Systems (GIS), and publicly available data. The system stores, sorts, and processes strategic geo-referenced data: pipelines infrastructure, transported volumes, sociodemographic factors, land use, illegal pipeline taps, and area impacted by oil pipelines incidents. By identifying the main factors that could impact the pipeline infrastructure, the system generates several graphical representations to assist in risk analysis. The work also analyses and proposes improved pipeline monitoring systems, emergency responses protocols, and non-technical tools to address operational and safety challenges for oil pipelines near local communities. The results provide valuable information for the formulation of policy and regulations to enhance pipeline safety. This work develops a comprehensive strategy based on data analysis, monitoring systems, emergency response protocols and non-technical tools to assist decision makers to improve operational safety and prevent events that could cause serious damage to local communities.

The aim of this paper is to present TOTAL E&P Angola (subsidiary of TOTAL in Angola, hereafter mentioned as "Affiliate") last environmental monitoring campaign. The document presents the strategy and summarizes the results of indicators which are used to follow up cumulative impacts on deep water environment. The campaign was performed between 1998 and 2015, and different laboratories were used. The impact of field operations proved to be rather low or negligible, and acceptable on the long term. Since February 1998, when the first environmental baseline study (EBS) was performed (in Block 17: Girassol) to describe the initial state of the environment, the Affiliate has been conducting regular offshore monitoring campaigns with the aim of characterizing the water column, and marine sediments around existing installations and developing fields. These surveys are not limited to Block 17, but also extend to other Affiliate offshore blocks in Angola. In March 2015, the Affiliate’s most demanding Global Environmental Baseline & Monitoring Survey (GEMS) was completed, which covered six different offshore blocks, with a work scope ranging between EBS and EMoS (environmental monitoring survey), comprising 226 sampling stations for sediment and benthic macrofauna, 26 for seawater, 17 for phytoplankton and 8 for foraminifera. Another specificity of this latest GEMS was the scientific vessel that was shared among Operators through a joint agreement, of course with some legal and operational constraints considering the socio-geographic context of the project. Technically, besides the Affiliate’s required guidelines and rules, the parameters to be tested also had to meet recent regulations from the Ministry of Petroleum. Physico-chemical and biological data obtained over the past 17 years have been used as indicators of environment quality, and its regular monitoring allows assessment of the sensitivity of the marine environment to petroleum activities.

Due to environmental requirements, produced water needs treatment prior to disposal or reuse. In recent years, the most successful solutions to treat produced water involve special attention to efficiency, cost, and environmentally safe treatment methods. Recent studies have shown encouraging results using amine-coated magnetite (Fe 3 O 4 ) nanoparticles to remove residual oil from produced water using a magnetic field. However, the manufacturing of magnetite nanoparticles requires an expensive coating operation, which limits the application of this technology in large-scale treatment operations. The goal of this study is to develop a simple, efficient, and economically feasible method for removing oil from produced water using nanoparticles. Iron oxide nanoparticles are biocompatible and even safely used in medical applications. This study focuses on the removal of residual oil from produced water using uncoated, recyclable and less expensive maghemite (g-Fe 2 O 3 ) nanoparticles. These particles have been shown the potential for removing oil layers from the surface of water. However, they have not been tested for their capability of removing emulsified and dissolved oil from produced water. In this study, commercial and synthesized maghemite nanoparticles were utilized. The maghemite nanoparticles were synthesized using the co-precipitation process. Lab-synthesized produced water samples with high oil concentration (1000 ppm) were prepared by mixing medium oil with brine (1180 ppm NaCl solution). The nanoparticles were dispersed in 3% by weight NaCl solution (3% NaCl brine) at varying concentrations (0.31 – 5 mg/mL) to form different nanosuspensions. Subsequently, the nanosuspensions were mixed with synthesized produced water for 10 min. When a magnetic field was applied to the mixture, a clear separation of the nanoparticles was observed within seconds. Residual oil in the samples was measured using non-dispersive infrared spectroscopy. Oil content analysis confirmed the successful removal of oil from the water samples. The oil content of the samples was reduced from 1000 to less than 10 ppm. For the real produced water samples, results showed a reduction of oil content to an undetectable level (i.e. less than 0.1 ppm). The ease of nanoparticle collection and washing after subsequent water treatments further demonstrates the feasibility of magnetic nanoparticle-based separations for large-scale use in produced water treatment operations. The unique finding of this study is the elimination of one additional step of synthesizing (amine coating) magnetic nanoparticles. Direct use of uncoated maghemite nanoparticles with high oil removal efficiency can reduce produced water treatment cost and promote this technology as an economically feasible option within the industry.

The Pluspetrol Camisea Biodiversity Monitoring Program (BMP) has been collecting data on the distribution and status of species of flora and fauna and provisioning ecosystem services within the 247,000 ha upstream area of influence since 2005. In order to synthesize, integrate and map a complex, long-term data set on species and provisioning ecosystem services (fishing, hunting and gathering by local communities) the BMP utilized Saaty’s analytical hierarchical process (AHP) to categorize sensitivity of stream basins within the Project Area of Influence. The BMP conducted a critical habitat analysis based on International Finance Corporation (IFC) Performance Standard 6 (PS6) using long-term monitoring data to inform the CHA, prioritize and map sensitive biodiversity values according to stream basin and landscape unit type. In addition, the BMP synthesized social data on provisioning ecosystem services based on data collected during household interviews, participatory resource mapping, and field data on bush meat biomass. Using AHP allowed the BMP to obtain an integrated biological and social database that facilitates mapping sensitive habitats at a relatively small-scale (stream basins). Pluspetrol utilizes the database and maps to inform their biodiversity management and residual impact reduction strategy. The combination of biological and social data with AHP is a useful tool for both Project management and sustainable land-use planning.

Incidents that have occurred in worldwide waters and in the Gulf of Mexico (GOM) have provided lessons for an enhanced approach and better content of Emergency Response and Control Plans (ERCP). The focus is to timely incorporate response aspects that must be taken into account from the early project stages. A complete, current ERCP is an effective mitigation control to limit consequences arising from uncontrolled loss of containment events. A sequence to develop an ERCP compliant with Mexican guidelines and regulations is presented. It involves the collection of information from the Environmental Impact Assessment (EIA) and Hazard Identification Analysis (HAZID) for the project. Credible major hazardous events, such as loss of containment scenarios, are extracted and analyzed to constitute the basis for ERCP development based on maximum credible estimated risk. Besides sound event planning content, the paper also discusses other key elements required to produce a complete and effective ERCP. The strategy includes the identification of ERCP requirements from different entities such as; financial institutions, oil and gas operators, local and regional legislation requirements applicable to GOM, and best-recognized emergency planning and response practices. Available project information sources include design bases, EIA, HAZID and Process Hazard Analysis (PHA) studies. The collected requirements are used to unfold the content of the ERP, including required elements such as Introduction, Incident Command System (ICS), Unified Command System (UCS), Emergency Scenarios, Action Plans per Accident Type, Available Sources, Training and Competencies, and Drills and Supporting Information. In addition, a flow chart for the ERCP is included describing the sequence of steps from the accident initiation, notifications, response, and recovery until the emergency transient has been adequately controlled. An ERCP implementation and content access is proposed as well in this paper.

Repsol Exploración Perú (Repsol E&P), in accordance with its environmental strategic lines for E&P, has been developing a plan to become certified as a responsible water user in its operations in Block 57. The certification is a recognition granted by the State (National Water Authority - ANA) through a seal or mark called "Blue Certificate". To obtain the certificate it is necessary to comply with 3 steps: Assessment of the Water Footprint Reduction of Water Footprint. Development of a shared value project. By obtaining the Blue Certificate contributes to the sustainability of the business, relationships with key stakeholders such as the State and the communities in the area of influence are maintained and improved. It also manages to optimize the processes that demand water resources in the operations; at the same time, the company is positioned within the sustainable business on water issues in the country.