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Collaborating Authors
Results
China's Early Stage Marine Shale Play Exploration: A Deep Asia Pacific Region Horizontal Multiple-Stage Frac: Case History, Operation, and Execution
Lv, Zonggang (PetroChina Southwest Oilfield Southern-Sichuan Branch) | Wang, Lin (PetroChina Southwest Oilfield Southern-Sichuan Branch) | Deng, Sufen (PetroChina Southwest Oilfield Southern-Sichuan Branch) | Chong, King Kwee (Halliburton) | Wooley, James S. (Halliburton) | Wang, Qiang (Halliburton) | Ji, Peng (Marks) (Halliburton)
Abstract During the past five years, shale gas developments have changed the game for the US natural gas industry. Globally, shale exploration activities are also increasing. China is in the early stages of exploiting the world's largest reserves of shale gas resources while attempting to cope with increasing energy demands. This paper presents a case history of applicable technology currently used in North America for initial attempts at shale gas exploration in China. This case study is the first Cambrian age marine shale well in the Qiongzhusi formation located in the shale-gas-rich Sichuan province. Many technologies were brought from North American shale gas applications for this well (Chong et al. 2010). This study describes the technologies used to drill and complete the targeted shale gas formation and guide the completion and stimulation design. The target formation was drilled horizontally and the casing was cemented. The formation was then stimulated with multiple stages after full integration of data from geologic, geomechanical, petrophysical, and core analysis, which aided in the fluid and proppant selection, proppant concentration, and the designed injection rate. A diagnostic fracture injection test (DFIT) was performed before the main treatment to confirm fracture gradient, closure, pore pressure, system permeability, and leakoff. Microseismic mapping was also used, which proved to be valuable when planning and assessing the fracturing results. Currently, the well is flowing gas at rates comparable to early production time in a typical North American shale gas well with a similar type of completion. This case study serves as an example of successful implementation of proven technology outside of the North America shale gas market. Continued projects such as this one are the predecessor to full-scale development of shale gas and have helped shape the abundant gas supply currently in the United States. Additionally, these types of projects are necessary to help China improve their future outlook on gas supply.
- Asia > China > Sichuan Province (0.89)
- North America > United States > Texas (0.68)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.68)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Oklahoma > Anadarko Basin > Cana Woodford Shale Formation (0.99)
- (6 more...)
Abstract INPEX has begun construction of one of the world's largest oil and gas projects following the Final Investment Decision (FID) on the US $34 Billion Ichthys LNG Project in Australia on 13 January 2012. The Ichthys LNG Project is a joint venture between INPEX (Operator) and Total with Tokyo Gas, Osaka Gas, Chubu Electric and Toho Gas. The Ichthys Field is situated in the Timor Sea approximately 200 kilometers off the Western Australian coast and over 800 kilometers from Darwin. Three exploratory wells drilled in 2000 and 2001 resulted in the discovery of an extremely promising gas and condensate field with resource estimates from two reservoirs totaling approximately 12TCF of gas and 500 million barrels of condensate. Conceptual studies, FEED and ITT followed and development leading to sanctioning of the Ichthys LNG Project by INPEX and Total. Gas from the Ichthys Gas-Condensate Field in the Browse Basin will undergo preliminary processing offshore to remove water and extract condensate. The gas will then be exported to onshore processing facilities in Darwin via an 889 kilometer subsea Gas Export Pipeline (GEP). Most condensate will be sent to a Floating Production Storage and Offloading (FPSO) vessel for stabilization and storage prior to being shipped to global markets. The Ichthys LNG Project is expected to produce 8.4 million tons of LNG and 1.6 million tons of LPG per annum, along with approximately 100,000 barrels of condensate per day at peak.
- Oceania > Australia > Western Australia > North West Shelf (1.00)
- Asia > Japan > Kantō > Tokyo Metropolis Prefecture > Tokyo (0.24)
- Asia > Japan > Kansai > Osaka Prefecture > Osaka (0.24)
- Oceania > Australia > Western Australia > Western Australia > Timor Sea > Browse Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Timor Sea > Browse Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Browse Basin > Caswell Basin > Ichthys Field (0.99)
- (3 more...)
Abstract Removing mercaptans from sour natural gas is becoming an important issue with the global trend towards more stringent specifications for commercial gases. Amines have been extensively used on account of their ability to meet severe H2S and CO2 specifications and very high acid gas selectivity over hydrocarbons. Amines however present very limited mercaptans removal capabilities, an additional treatment step is generally required to achieve a stringent specification of total sulfur specification in the sales gas or upstream liquefaction plant. Total, taking advantage of its extensive know-how and experiences in acid gas removal, has developed the HySWEET processes, for simultaneous absorption of acid gases and mercaptans. This technology relies on a new hybrid solvent formulation allowing limited coabsorption of hydrocarbons and improved energy efficiency. The HySWEET process has been in operation since 2008, and the entire gas production of the Lacq plant, France is now treated with this new hybrid solvent. The industrial feedback has confirmed not only higher mercaptan removal, but also lower energy consumption when compared to the AdvAmine™ HiLoadDEA process which has allowed for Lacq gas treatment during most of the lifetime of the field. The development of the HySWEETDEA process is now completed and ready for commercialization. An optimized design can now be proposed for any application case targeting total CO2 and H2S removal along with a stringent total sulfur specification. Thousands of laboratory measurements (i.e. thermodynamics, kinetics, physical properties) have been used to develop a rigorous simulation tool which relies on rate-based transfer models validated against extensive pilot and operational test-runs. The HySWEETMDEA process is under development, for the selective elimination of sulfur compounds over CO2. Improved mercaptan removal and high energy efficiency have been demonstrated during pilot tests. These pilot test results will be later used to validate the prediction of the simulation tool currently under development. This paper provides a review of the HySWEET technology: an update on the HySWEETDEA process and the latest R&D developments of HySWEETMDEA.
- Europe (1.00)
- North America > United States (0.46)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Health, Safety, Environment & Sustainability > Health > Noise, chemicals, and other workplace hazards (1.00)
- Facilities Design, Construction and Operation > Processing Systems and Design (1.00)
Offshore Drilling Waste Discharge: Egyptian Environmental Regulations
Agwa, Ahmad (Development Drilling Group, Kuwait Oil Company KOC) | Sadiq, Rehan (Okanagan School of Engineering, The University of British Columbia, Kelowna, BC, Canada) | Leheta, Heba (Naval Architecture and Marine Engineering Department, Faculty of Engineering, Alexandria University, Alexandria, Egypt)
Abstract Egypt is located in the Northeast of Africa where oil and gas (O&G) are produced offshore from the Gulf of Suez and the Southeast part of the Mediterranean. The O&G production in Egypt is distributed as follows: 70% Gulf of Suez, 16% Western desert, 8% Sinai Peninsula and 6% Eastern desert. Past O&G activities, refining and transport have resulted in chronic pollution in Egyptian offshore, and numerous environmental programs have been initiated to protect new development areas from the environmental impacts. The offshore drilling process uses drilling fluids (muds) and generates waste fluids and cuttings, which could be the largest discharges going into the receiving water bodies. Water-based drilling fluids are commonly employed for drilling in Egyptian offshore because of their expected environmental benign behavior in the marine environment. The main objective of this paper is to highlight relevant Egyptian environmental regulations and explain several options to manage offshore drilling wastes: offshore discharge, offshore down-hole injection and onshore disposal.
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- Geology > Mineral (0.73)
- Geology > Geological Subdiscipline (0.47)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment (0.35)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Health, Safety, Environment & Sustainability > HSSE & Social Responsibility Management > HSSE standards, regulations and codes (1.00)
- Health, Safety, Environment & Sustainability > Environment > Waste management (1.00)
Abstract Gas Processing Facility (GPF) project achieved Zero flaring 1.7million standard cubic feet per day (41.65 tons) gas recovered thru Vapor Recovery System and protect the environment by reducing; CO2: 3,924 tons/yr CO: 123.6 tons/yr NOx: 21.6 tons/yrs ➢Total gas recovered: 612 million standard cubic feet per year ➢Revenue saving: 835,380 US$ /year Vapor Recovery Unit (VRU): Under this unit, gases from the Tertiary Ethyl Glycol (TEG)Dehydration package and vents from compressors dry gas seals are recovered/ captured and compressed in the VRU and then sent to the suction for the main gas compressor for reuse instead of going to flare Gas Processing Project (GPF) at Zakum complex is a new gas treatment platform that will augment the existing gas processing capacity of the Zakum West Super Complex. It will increase the associated gas production from Zakum oilfield. The beauty of this project is that ADMA has employed the Zero flaring policy. There will be no flaring at all at this platform. This is one of the unique project of its nature in the ADNOC group of companies, even in Emirates and could be in the whole middle east where is there would be NO flaring. We have designed flare as well in this project but that would be used only for emergencies. GPF is a stand alone platform with independent utilities and support facilities. The GPF platform is 67.5 meter in length and 43 meters in width. GPF is located at Zakum oilfield, offshore facility about 65 kilometer Northwest of Abu Dhabi. This platform has three main decks, cellar, mezzanine and main. The flare structure consists of a 120 meter long flare bridge with a 80m above sea level angled boom. The distance from the flare tip to the GPF platform is 150 m. There will not be any flaring during normal operation of the GPF, as Zero flaring technology is installed. Hydrocarbon from the GPF platform will be recovered using a Vapour Recovery Unit (VRU) facility. Flaring will only be undertaken during emergency conditions.
- Asia > Middle East > UAE > Abu Dhabi Emirate > Arabian Gulf (0.46)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.36)
Abstract Ocean Bottom Cable (OBC) seismic survey has several technical advantages over conventional towed streamer technique. However, its usage is still limited as requirement of relatively large operational efforts likely results in more survey cost and duration. Moreover, OBC seismic operations could affect other field activities and multi-vessel operations required for OBC survey and longer survey duration potentially increase HSE risks in fields. Consequently, enhancement and optimization of OBC survey productivity is essential particularly in specific situations such as shallow water, congested producing oil/ gas fields (e.g. Offshore Abu Dhabi) and in environmentally restricted areas. Although several studies have been carried out to establish key parameters, designs and geometries for high OBC survey productivity, the current developments in the seismic industry technology and equipment are enabling to establish a variety of survey designs and geometries which were not feasible previously. Therefore, our study was conducted with the aim to analyze the impact of OBC Survey Designs / Geometries on productivity considering the current available equipment and technology and meeting the established geophysical survey objectives. Applications of dual source operations were also discussed by using two cases: (1) Distanced Separated Simultaneous Shooting (DS3); and (2) Dual Source Vessel Flip-Flop Shooting (DSVFFS). Dual source operations for both marine streamer and land cases have been well described whereas few examples of its applicability to OBC survey have been presented. In this paper, we described the impact of dual source operations on OBC survey efficiency and technical challenges determined from the relationship between OBC Survey Geometries/Designs and interference noise wave fields which have to be considered as more complex scenario than other types of surveys. We believe that the established new approach will assist to acquire future OBC survey with high productivity and in a very cost effective manner.
Abstract ADCO integrity policy calls for ensuring that the new assets are designed to fit the intended services, engineered and constructed in accordance with approved company specifications. The execution strategy of the Asset Integrity Management System (AIMS) requirements is based on progressive implementation starting as early as initiation phase of the project. ADCO integrity requirements are in line with the requirements of Shell DEP standards that taken as the technical basis for Front end Engineering Design (FEED) and Engineering Procurement and Construction (EPC). The main integrity services within EPC scope include assignment of asset coding, assessment / identification of the asset HSE & Business criticality, development and implementation of supply Quality Assurance/ Quality Control (QA/QC) philosophy document, establish and implement a project specific Management of change procedure. Several AIMS reviews are in place and shall be conducted at definite mile stones of the project life cycle that guarantee the quality of the set specific Integrity deliverables. The purpose of this paper is to share ADCO's experience during project execution, both in terms of technical and project quality/ integrity management issues. The projects integrity practices implemented throughout the lifecycle of the project, starting with conceptual and preliminary engineering, through detailed engineering, procurement and construction are highlighted in the paper.
Abstract Subsea Pipelines Repair When they are located subsea, damaged pipelines are very challenging to repair. The extreme conditions, the risks related to pollution and the high daily rates of intervention vessels make the repair decision difficult. Recently, composite repair solutions, originally developed for onshore use, where adapted for subsea application and tested, so as to get alternative solutions to apply when classical repair methods are not suitable or too costly. Composite repair system for subsea use Composite repair solutions for restoring the structural integrity of damaged pipeline have been available for some time. A modified version was specifically designed for subsea pipeline repair, using a dedicated resin applicable under water. The repair system is designed to be installed by divers with a semi-automatic installation process: using pre-impregnated tape with a specific tool applying constant tension and winding path. This tool is now being adapted for ROV use, to allow performing deepwater repairs. Results, Observations, and Conclusions Several test campaigns, both in swimming pools and subsea were performed in Monaco, Abu Dhabi and in China for various oil operators, with a rigorous test protocol, supervised by a third party. A finite element model of the composite repair allows calculating the number of layers, pattern and extent over the defect, in relation to the stress level in the pipe. This FE model was also validated through numerous burst tests, confirming the reliability of the calculations. The subsequent pressure test results indicated that the pipeline integrity was fully restored for damages such as metal loss and through thickness defects. A solution for restoring the structural integrity of a damaged pipeline This composite repair system is designed to restore fully the structural integrity and pressure resistance of the pipeline for subsea application. It represents a cost efficient alternative to classical repair methods involving clamps, mechanical connectors or others.
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.35)
- Europe > Monaco (0.25)
- Asia > China (0.25)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the Abu Dhabi International Petroleum Exhibition & Conference held in Abu Dhabi, UAE, 11-14 November 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Jarring is a cost effective alternative to free stuck pipe. Impact tools have been used in drilling industry for many decades and the technology has helped operators save significant amounts of time and money. To keep improving this technology, a new Drilling Impact System (DIS) has been developed. The DIS uses innovative double-acting hydraulic Drilling Jar/Drilling Accelerator and BHA analysis software.
- North America > United States (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.74)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Equipment (1.00)
Abstract Optimize early oil production facilities for a H2S environment Companies active in Exploration & Prodution (E&P) are entering blocks with the target to explore and find new Hydorcarbons (HCs). Probably most of those E&P companies are chasing "early roduction", once they have discovery promising a feasible commercial discovery. Moreover, this early productionshould be done in an optimized way. This paper outlines the approach that OMV has taken in order to "optimize the early oil production in an H2S environment" for a block in Kurdistan, Region of Iraq. Looking at the project environment, the first question we needed to answer ourselves was: Optimized in which respect? Highest safety / HSSE standards? High H2S (> 10% in the associated gas) content encountered in the DST! Shortest time for oil to produce, deliver and commercialize? Earliest possible production with standard equipment from the shelf Maximize initial oil production? Just produce to the limit with no proper knowledge (no appraisal done yet) of the reservoir and the reservoir drive. The answer to the above questions was not an easy one, however, with HSSE being OMV's priority in all operations "SAFETY First!" has been clear from the very beginning. Independent from all other technical and business issues, OMV started a "Pre development Study" with the target to have a plan forward, if we would encounteroil in commercial quantities. Actually, that study was started prior (!) to the spud of the first Exploration well. this created certain costs, but the study provided valuable input for the definition of our "optimized" solution under the given project environment. The following steps in the project definition and developmentwill be introduced in detail at the SPE conference: Conduct Pre-Development Study: Identify country specific basics Opportunity Framing with definition of scenarios "Do we look wide enough?" Define the "optimized - preferred scenario" Minimum economic field size: Prove the Scenario (OPEX+CAPEX) against the MEF Prepare contracting / procurement strategy Prepare and float the invitation to tender for the early production facilities