From Early Production Systems to the Development of Ultra Deepwater Fields - Experience and Critical Issues of Floating Production Units

Mastrangelo, Carlos Ferraz; Barusco, Pedro J.; Formigli, Jose; Dias, Ronaldo

doi:10.4043/15224-ms

“…The future treatments should use potassium based product. 5. The treatment volume should provide one meter invasion radius.…”

Section: Scale History In the Campos Basin 12-21mentioning

confidence: 99%

“…The two first fields, Garoupa and Enchova, lay in 120 m WD, which was deep water, at that time. The usual approach of fixed platforms required long time for planning, construction and installation 3,5 . This scenario and context were the drivers for the daring initiatives, implementation of new technologies, concise studies and, risk assumption.…”

Section: Introductionmentioning

confidence: 99%

Formation Damage History in the Mature Fields of Campos Basin Offshore Brazil

Rodrigues

¹

,

Neumann

²

,

Miura

³

et al. 2007

Proceedings of European Formation Damage Conference

3

0

View full text Add to dashboard Cite

fax 01-972-952-9435. AbstractThe Campos Basin mature fields, offshore Brazil, including the Marlim Field, are usually referred to as the World's deepwater field laboratory. The development of these fields was driven by the Brazilian state energy needs throughout the seventies and eighties, which induced a strategy of accelerating the projects implementation and anticipating their first oil. This sense of urgency is still dominant in Brazilian oil politics and has recently enabled the country to reach its oil self-sufficiency. That scenario throughout the last two decades encouraged risk assumption as well as the implementation of a considerable number of new technologies. Fifteen years after the first oil production from Marlim it seems that more engineered solutions are replacing the daring initiatives and the concise studies carried out in the beginning. Those years also testified an outstanding evolution of the drilling and completion technologies. The development advance to deeper and deeper waters brought up unpredicted problems such as wax deposition and hydrate formation. Thus, the history of the mature deepwater fields of Campos Basin offers great opportunities for learning, in a wide perspective. This paper summarizes the history of the damage and main completion troubles associated to Campos Basin deepwater mature fields. The aspects of prediction, prevention and remediation of the formation damage associated to drilling, sand control, stimulation, fines migration, organic deposition, scale, souring and other minor issues are addressed. The paper also presents some statistical data, predicted and unpredicted problems, and the ways they have and are currently handled. The technologies evolution and the most recent challenges are also shown. It is our belief that other deepwater mature fields to be developed and the new systems to be designed will certainly benefit from the experiences and lessons learned in the deepwater mature fields of Campos Basin. SPE 106389porosities, requiring the installation of sand exclusion systems, either in the producers or injectors wells. The development of the deep and ultra-deep fields has been accomplished by using floating platforms and subsea completions, associated to complex subsea layouts. The wells evolved from vertical and deviated to complex horizontal and extended reach, high rate ones. In this scenario damage is usually very expensive to be removed and implies large production loss.This paper provides a summary of the CB context evolution throughout the years with respect to: national energy politics, technological challenges, human resources, organizations structures, and the history of offshore installations. It also presents a section on damage identification methodology and its history considering the type of damage, and finally a few conclusions.

show abstract

Formation Damage History in the Mature Fields of Campos Basin Offshore Brazil

Rodrigues

¹

,

Neumann

²

,

Miura

³

et al. 2007

View full text Add to dashboard Cite

fax 01-972-952-9435. AbstractThe Campos Basin mature fields, offshore Brazil, including the Marlim Field, are usually referred to as the World's deepwater field laboratory. The development of these fields was driven by the Brazilian state energy needs throughout the seventies and eighties, which induced a strategy of accelerating the projects implementation and anticipating their first oil. This sense of urgency is still dominant in Brazilian oil politics and has recently enabled the country to reach its oil self-sufficiency. That scenario throughout the last two decades encouraged risk assumption as well as the implementation of a considerable number of new technologies. Fifteen years after the first oil production from Marlim it seems that more engineered solutions are replacing the daring initiatives and the concise studies carried out in the beginning. Those years also testified an outstanding evolution of the drilling and completion technologies. The development advance to deeper and deeper waters brought up unpredicted problems such as wax deposition and hydrate formation. Thus, the history of the mature deepwater fields of Campos Basin offers great opportunities for learning, in a wide perspective. This paper summarizes the history of the damage and main completion troubles associated to Campos Basin deepwater mature fields. The aspects of prediction, prevention and remediation of the formation damage associated to drilling, sand control, stimulation, fines migration, organic deposition, scale, souring and other minor issues are addressed. The paper also presents some statistical data, predicted and unpredicted problems, and the ways they have and are currently handled. The technologies evolution and the most recent challenges are also shown. It is our belief that other deepwater mature fields to be developed and the new systems to be designed will certainly benefit from the experiences and lessons learned in the deepwater mature fields of Campos Basin. SPE 106389porosities, requiring the installation of sand exclusion systems, either in the producers or injectors wells. The development of the deep and ultra-deep fields has been accomplished by using floating platforms and subsea completions, associated to complex subsea layouts. The wells evolved from vertical and deviated to complex horizontal and extended reach, high rate ones. In this scenario damage is usually very expensive to be removed and implies large production loss.This paper provides a summary of the CB context evolution throughout the years with respect to: national energy politics, technological challenges, human resources, organizations structures, and the history of offshore installations. It also presents a section on damage identification methodology and its history considering the type of damage, and finally a few conclusions.

show abstract

Equalization of the Water Injection Profile of a Subsea Horizontal Well: A Case History

Amaral

¹

,

Augustine

²

,

Henriksen

³

et al. 2008

SPE International Symposium and Exhibition on Formation Damage Control

View full text Add to dashboard Cite

This paper focuses on the first global installation of a water injector well with a lower completion system that incorporates both premium sand control screens and water injection profile equalization. The equalization of the water injection profile of horizontal wells has been a key issue in many development projects worldwide and has the potential to increase the reservoirs ultimate recovery by increasing the water sweep efficiency. Inflow Control Devices integrated with premium sand control screens have a long history of application in production wells. In these cases the main objective is to create a uniform inflow profile along the horizontal section, delaying unwanted water and gas production and increasing oil recovery. The method through which Inflow Control Devices equalize the inflow of oil can also be used to equalize the outflow of water. Historically, sand control completions for water injection wells include stand-alone conventional screens and open-hole gravel packs. Stand-alone conventional screen completions do not provide equalization of the water injection profile. Open-hole gravel packs provide for an effective acid treatment of the water injector well but present operational risks, high costs, as well as expensive rig time. The installation was carried out in a subsea horizontal sea water injector well in the Campos Basin, offshore Brazil. The paper presents the overall completion plan, the lower completion installation, the acid treatment through the Inflow Control Devices, and the initial water injection results based on production logs and water injectivity tests. The main concerns during the planning phase are discussed, highlighting the procedures adopted to overcome them. The good initial results have created the expectation of many applications of this system in Campos Basin. It is believed that sharing this information will benefit many operators with horizontal water injectors in their field development plans. Marlim The Marlim field, located in the northeastern part of Campos Basin, about 110 km offshore in the state of Rio de Janeiro, was discovered in January 1985. The field covers an area of about 145 km2, in water depths ranging from 600 m (1968 ft) to 1,100 m (3609 ft). The Oligocene sandstone reservoir quality is good. Core analyses of several wells indicate mean permeability of 2,000 md, mean porosity of 30%, and highly friable sandstone. Marlim's reservoir development strategy relies heavily on water injection as a source of reservoir energy maintenance. Currently 9 Floating Production Systems (FPS) are on stream with 129 subsea wells on operation (83 producers and 46 water injectors), including 36 horizontal wells. The total production reached its peak of 650,000 bbl/d in 2002, overcoming all former production forecasts. Currently Marlim field oil production, around 450,000 bbl/d, is supported by injecting 760,000 bbl/d of sea water. The recovery factor to date is 22.9 %. The water production is 217,150 bbl/d (water cut of 33 %) and GOR is equal to the initial solubility ratio, 83 STD m3/STD m3. Water injection is into the oil leg, concentrated in the lower portions of the reservoir and production is concentrated in the upper parts, to delay water breakthrough. A thorough history of the Marlim field can found in references 1 through 6. Injection Well Strategy The water injector well under consideration for this project was to be located in the south area of the Marlim field. This injector well was planned for pressure maintenance and for sweep efficiency in the thin reservoir border of the field. The injector well, IN, and its neighboring producer wells, A, B, C, and D are shown in Figure 1.

show abstract

From Early Production Systems to the Development of Ultra Deepwater Fields - Experience and Critical Issues of Floating Production Units

Cited by 7 publications

References 0 publications

Formation Damage History in the Mature Fields of Campos Basin Offshore Brazil

Formation Damage History in the Mature Fields of Campos Basin Offshore Brazil

Formation Damage History in the Mature Fields of Campos Basin Offshore Brazil

Equalization of the Water Injection Profile of a Subsea Horizontal Well: A Case History

Contact Info

Product

Resources

About