Waterflood Strategy, Challenges and Innovations

Kenawy, F.A.; Bibars, O.A.; Hanafy, H.H.; Rezk, A.S.

doi:10.2118/53136-ms

Middle East Oil Show and Conference 1999

DOI: 10.2118/53136-ms

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Waterflood Strategy, Challenges and Innovations

F.A. Kenawy¹,

O.A. Bibars

H.H. Hanafy

et al.

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractMore than twenty four years ago, Gupco (Gulf of Suez Petroleum Company) initiated the first waterflood project in Egypt for the giant El Morgan oil field. With continuing waterflooding experience, Gupco has applied this improved recovery method for other fields. Currently Gupco operates 14 different waterflood reservoirs. These reservoirs have produced a cumulative oil representing 40% of their original oil-in-place. On average, the projected waterflood recov… Show more

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Cited by 5 publications

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Water Injection Patterns Optimization Approach on High-Viscous Oil in Russkoye Field

Zakirov¹,

Shayhutdinov²,

Svarovskaya³

et al. 2012

All Days

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Russkoye field, discovered in 1968, is a giant high-viscous oil field located above the Polar Circle in Russia. The commercial development of the field has been a tremendous challenge due to several factors such as a very complex heterogeneous shallow reservoir with a large gas cap, an active bottom aquifer, unconsolidated sands, low temperature, and permafrost zone. At this stage, the development of the field is still on the pilot testing stage in order to understand and evaluate different possible development strategies that assure the maximum recoverable reserves for this kind of field. As part of the development strategy, eight water injection pattern schemes including horizontal and vertical wells, and different well spacings were simulated to find the optimal waterflooding patterns, and to evaluate different well trajectories, and different injection bottomhole pressures, for the next pilot area. The water injection pattern schemes evaluated were horizontal wells line drive, 7-spot, 7-spot inverted, 9-spot, 9-spot inverted, 5 spot, combined line drive with horizontal producers and two deviated injectors, and combined line drive with horizontal producers and three deviated injectors. The complete analysis was carried out on the basis of the technical results and the economical evaluation. Several parameters were studied to compare performance and efficiency of different water injection patterns, such as voidage replacement ratio, cumulative oil, water and gas, production profiles, sweep efficiency, injected pore volume, and reservoir pressure behavior. The optimization of the four well spacings between 100 m and 400 m and the injection bottomhole pressure range was performed using an analytical approximation. The economical evaluation for each water injection pattern analyzed was executed by means of the economical standard analysis: net present value, internal rate of return, profitability index, lifting cost, and payback period.

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Water Injection Patterns Optimization Approach on High-Viscous Oil in Russkoye Field

Zakirov¹,

Shayhutdinov²,

Svarovskaya³

et al. 2012

All Days

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Maximizing Recovery from Peripheral Waterflooding: Case History of Two Water Injectors

Adegboye¹,

Okpan²

2015

All Days

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Reservoir X01 and X02 are among the biggest reservoirs in AA field located in shallow waters offshore Nigeria. Production started from both reservoirs in 1965. By year 2001, the reservoir pressure in both X01 and X02 had each depleted by about 45% from their initial pressure. Furthermore, the reservoirs were observed to exhibit multiple pressure regions and fluid contacts at dynamic condition resulting from stratigraphic variation and differential production and injection across the reservoirs. Water injection commenced in 2002 into both reservoirs through peripheral waterflooding. It was observed that only the eastern regions of the reservoirs were benefitting from the water injection. By year 2011, reservoir pressure and production from the western region of both reservoirs had depleted significantly; several wells quit production while others had their production rate reduced. Utilizing historical pressure data, production data and other reservoir information, dynamic simulation was constructed to assess the impact of drilling two water injectors, Inj-03i and Inj-05i, in the western areas of reservoirs X01 and X02 respectively. The injectors were needed to provide pressure support as well as to improve sweep efficiency. In October 2011, Inj-03i and Inj-05i commenced water injection into the western region of X01 and X02 reservoirs respectively. By February 2013, reservoir pressure in the western area of X01 reservoir had risen to 1700 psi, from its pre-water injection value of 1000 psi. Similarly in the western area of X02 pressure increase of 300 was observed post water injection in Inj-05i. Three wells that had earlier quit production in X01 reservoir were restored back to production while two shut-in wells in X02 reservoir were also restored to production. A total incremental production of 5,500 BOPD was attributed to the improved performance in the two reservoirs as a result of the drilling of the two water injectors. Recent flowing and static pressure data were valuable in designing production restoration jobs.

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Case Study of a Super-Giant Field Rejuvenation

Xiong

et al. 2016

SPE Europec Featured at 78th EAGE Conference and Exhibition

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Many oilfields in the world are mature and developed at the later stages of their life, and how to rehabilitate these fields is the biggest challenging problem. This paper presents an integrated approach with multi-disciplines to rejuvenate one of the world's super-giant oilfields in Middle East. The K super-giant oilfield have more than 60 years' production history. Current oil recovery of the field is over 50% with more than 60% prolonged shut-in wells, and higher than 10% annual decline rate. The proposed integrated rejuvenation approach involved the analysis of comprehensive multi-disciplines, from geology and reservoir engineering understanding, to completion, stimulation, and surface facilities analysis. And based on the analysis results, shut-in wells are ranked into different types respectively, different treatments are applied according to well rank. Production rate of producing wells are optimized based on integrated models. New well candidates and other well work are also proposed. For K oilfield, prolonged shut-in wells are classified into 4 ranks by principal component analysis, which mainly based on the understanding from bottom hole pressure evaluation, remaining oil description, offset well performance analysis, status of surface facilities, etc. Wells of rank 1 can be potentially open blowing directly with oil rate higher than 3000 mbd, and wells of rank 2 need install new ESP for artificial lift with oil rate only between 2000 mbd and 3000 mbd. While wells of rank 3 have much surface facilities problems and much lower potential oil rate, and wells of rank 4 have no potential to re-open. Also, an integrated model with subsurface, wellbore and surface facilities combined are established for production optimization. Based on the model, performance of producing wells can be analyzed, and flowing path or linkage pipeline of some wells were changed in order to meet the potential capacity of the well and surface facilities. Infilling well candidates are selected through pressure and remaining oil distribution analysis, which are mainly placed at the crest areas. Furthermore, other well works such as re-perforating, sidetracking, are also implemented with successful results. This study details a successful application of an integrated field rejuvenation approach for a super-giant field, which stabilized the production of the field at the first year and made a 10% production rate increment for the second year. Most importantly, the methodology presented can be adopted in other similar mature fields.

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Waterflood Strategy, Challenges and Innovations

Cited by 5 publications

References 10 publications

Water Injection Patterns Optimization Approach on High-Viscous Oil in Russkoye Field

Water Injection Patterns Optimization Approach on High-Viscous Oil in Russkoye Field

Maximizing Recovery from Peripheral Waterflooding: Case History of Two Water Injectors

Case Study of a Super-Giant Field Rejuvenation

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