The Hermes oil field: a small field takes wings

2009 ◽  
Vol 49 (1) ◽  
pp. 221 ◽  
Author(s):  
Greg C Smith ◽  
Jai Louis ◽  
Roy White ◽  
Ritu Gupta ◽  
Roger Collinson
Keyword(s):  
Scenario Analysis ◽  
Flow Line ◽  
Field Potential ◽  
Statistical Design ◽  
High Water ◽  
Oil Field ◽  
Oil Accumulation ◽  
Field Development ◽  
Uncertain Variables ◽  
Water Cut

The Lambert field was discovered in 1973 with oil reservoired in Tithonian turbidites. It was viewed as uneconomic until 1996 when re-evaluation led to discovery of the adjacent Hermes oil accumulation by Lambert–2. The Lambert–3 producer was drilled nearby to Lambert–2 in 1997 and tied back to the Cossack-Pioneer floating production storage offloader (FPSO). Lambert–3 was expected to drain about 25 MMBBLs of oil, coming off plateau after one year and declining substantially thereafter; however, it had produced more than 52 MMBBLs of oil by late 2008 without any water cut and may produce much more in the next 15–20 years. In contrast, several appraisal and production wells drilled since in the adjacent Lambert accumulation have only produced modest recoveries. Why were the original deterministic views of the Lambert-Hermes field so far from present estimates? This paper describes the approach taken to re-assess the Lambert and Hermes oil accumulations. First, the traps were reviewed by framing the main uncertain variables followed by a rigorous scenario analysis of the field. The work was expedited by using a statistical design to substantially reduce the number of scenarios required for modelling and simulation. The results included a statistical analysis and produced a better view of the probable reserves ranges. Remarkably, after 11 years’ production the field potential warranted re-appraisal. The scenario analysis indicated which uncertain variables needed attention and helped to select well locations. The results of appraisal should decide between several re-development options. The main possibilities for new field development include: drilling of additional oil producers; water shut-off in some producers; an additional flow-line to de-bottleneck oil production from Lambert and Hermes; re-instatement of a gas-injection line for gas-lift of wells at high water-cut; and installation of a new manifold further north in the Hermes accumulation to optimise field recovery.

Unlocking Field Potential of Mature Fields Using Hybrid Fuzzy Modelling and Kriging Method

2021 ◽  
Author(s):  
Saransh Surana
Keyword(s):  
Oil And Gas ◽  
Field Potential ◽  
High Water ◽  
Production Optimization ◽  
Secondary Development ◽  
Wellhead Pressure ◽  
Mature Field ◽  
High Water Cut ◽  
Water Cut ◽  
Well Data

Abstract Reservoir uncertainties, high water cut, completion integrity along with declining production are the major challenges of a mature field. These integrated with dying facilities and poor field production are key issues that each oil and gas company is facing these days. Arresting production decline is an inevitable objective, but with the existing techniques/steps involved, it becomes a cumbersome and exorbitant affair for the operators to meet their requirements. In addition, incompetent and flawed well data makes it more challenging to analyze mature fields. Although flow rate data is the most easily accessible data for mature fields, the absence of pressure data (flowing bottom-hole or wellhead pressure) remains a big obstacle for the application of conventional production enhancement and well screening strategies for most of the mature fields. A real-time optimization tool is thus constructed by developing a hybrid modelling technique that encapsulates Kriging and Fuzzy Logic to account for the imprecisions and uncertainties involved while identification of subsurface locations for production optimization of a mature field using only production data. The data from the existing wells in the field is used to generate a membership function based on its historical performance and productivity, thereby generating a spatial map of prospective areas, where secondary development operations can be taken up for production optimization.

Optimization Design for Oil-Water Separator of Injection-Production Technology in the same Well

2013 ◽  
Vol 803 ◽  
pp. 383-386
Author(s):  
Shu Ren Yang ◽  
Di Xu ◽  
Chao Yu ◽  
Jia Wei Fan ◽  
Cheng Chu Yue Fu
Keyword(s):  
Production Technology ◽  
Optimization Design ◽  
Large Scale ◽  
High Water ◽  
Oil Field ◽  
Production Costs ◽  
Water Separator ◽  
Oil Water ◽  
High Water Cut ◽  
Water Cut

In order to solve the problem of high water cut wells in some oil field in Daqing that it could not get the large-scale application because of the bad separating effect of down hole centrifugal oil-water separator, we optimize the design of multi-cup uniform flux oil-water separator according to the similar separation principle of multi-cup uniform flux gas anchor, and it is obtained to achieve of injection-production technology in the same well which is of high water cut. The design concept of the separator is increasing the number of opening every layer and aperture gradually in subsection from up to down in the design process. The purpose is to get the close intake quantity of every orifice and guarantee the residence time is long enough in the separator, effectively shorten the length of down hole oil-water separator and reduce the production costs and operating costs.

Research on Methods of Separate Stratum Injection Allocation in High Water Cut Stage

2013 ◽  
Vol 868 ◽  
pp. 645-650
Author(s):  
Lin Li
Keyword(s):  
Material Balance ◽  
High Water ◽  
Small Error ◽  
Oil Field ◽  
Petroleum Reservoir ◽  
Injection Wells ◽  
Single Well ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut

The parameters of reservoir impact all the sectors of oilfield developing after flood development, so methods of separate stratum injection allocation are researched for forecasting the petroleum reservoir performance accurately. The methods of separate stratum injection allocation are significative for remaining oil distribution, injection allocation of interval and the level of exploitation and administration in high water cut stage. First, we should derive injection-withdrawal ratio (IWR), gradient of pressure and water cut by material balance equation.The injection allocation of single well,injection wells and property of interval are determined by the research of split coefficient.We find the reservoir small error, lower water cut, high degree of reservoir recovery by anaysising the results of separate stratum injection allocation.The results show that separate stratum injection allocation is scientific and reasonable, simple and applied for the oil field in high water cut stage.

Fracture Treatment Design in the Lower Miocene Reservoir, Offshore Viet Nam

2021 ◽  
Author(s):  
Truong Nguyen Huu
Keyword(s):  
Production Rate ◽  
Oil Production ◽  
High Water ◽  
Oil Field ◽  
Base Case ◽  
Fracture Conductivity ◽  
Lower Miocene ◽  
High Water Cut ◽  
Water Cut ◽  
Fractured Well

Abstract In the past decades, most oil explotation in the White Tiger oil field was produced from the basement reservoir. However, in recent years, these pay zones consist of basement reservoirs, Oligocene reservoirs, and Miocene reservoirs of which oil field s have been declined in oil production rate due to several issues such as complex fracture network, high heterogeneity formation, high water cut, and the reduction of reservoir pressure. The huge issues in the most production wells at basement reservoir were high water cut and it has been significantly increasing during oil production yearly. Therefore, the total amount of oil production in all pay zones sharply decreased with time. At present, the lower Miocene reservoir is one of the best tight oil reservoirs to produce oil extractrion. The lower Miocene reservoir has been faced some issues such as high heterogeneity, complex structure, catastrophic clay swelling, low connectivity among the fractures, low effective wellbore radius and the reservoir that is hig h temperature up to 120°C, the closure pressure up to 6680psi, reservoir pressure up to 4500 psi, reservoir depth up to 3000m. Another reason low conductivity consists of both low reservoir porosity ranging from 1% of the hard shale to 10% of the sandstone formation, and the low permeability raining from 1md to 10md. By considering the various recovery methods, the integrated hydraulic fracturing stimulation is the best tool to successfully stimulate this reservoir, which method allows an increase in oil production rate. In the post fractured well has been shown an increase in productivity over 3 folds in comparison with the base case with fracture half-length nearly 75m, and fracture conductivity about 5400md.ft, which production rate is higher than the production rate of the base case. In addition, the proppant mass is used of 133,067 lbs of which the first main stage is to pump sinter lite bauxite proppant type of 20/40 into the fractures and the next big stage is to pump sintered ball bauxite proppant size of 16/30 into the fractures, which not only isolate proppant flow back but also increase fracture conductivity at the near wellbore as wel as high productivity rate after fractured well. To improve proppant transport, fract uring fluid systems consist of Guar polymer concentration of 11.2 pptg with these additives to form a total leak-off coefficient of 0.00227 ft/min0.5.

Conceptual Field Development Plan for X Field

2021 ◽  
Author(s):  
Khadijah Ibrahim ◽  
Petrus Nzerem ◽  
Ayuba Salihu ◽  
Ikechukwu Okafor ◽  
Oluwaseun Alonge ◽  
...  
Keyword(s):  
Capital Expenditure ◽  
Probabilistic Approach ◽  
Cost Effective ◽  
Oil Field ◽  
Development Plan ◽  
Recovery Factor ◽  
Reservoir Rock ◽  
Production Forecast ◽  
Field Development ◽  
Water Cut

Abstract The development plan of the new oil field discovered in a remote offshore environment, Niger Delta, Nigeria was evaluated. As the oil in place is uncertain, a probabilistic approach was used to estimate the STOOIP using the low, mid, and high cases. The STOOIP for these cases were 95 MMSTB, 145 MMSTB and 300 MMSTB which are the potential amount of oil in the reservoir. Rock and fluid properties were determined using PVT sample and then matched to the Standing correlations with an RMS of 4.93%. The performance of the different well models were analyzed, and sensitivities were run to provide detailed information to reduce the uncertainties of the parameters. Furthermore, production forecast was done for the field for the different STOOIP using the predicted number of producer and injector wells. The timing of the wells was accurately allocated to provide information for the drillers to work on the wells. From the production forecast, the different STOOIP cases had a water cut ranging from 68-73% at the end of the 15-year field life. The recoverable oil estimate was accounted for 33.25 MMSTB for 95 MMSTB (low), 55.1 MMSTB for 145 MMSTB (mid) and 135 MMSTB for 300 MMSTB (high) at 35%, 38% and 45% recovery factor. Based on the proposed development plan, the base model is recommended for further implementation as the recovery factor is 38% with an estimate of 55.1 MMSTB. The platform will have 6 producers and 2 injectors. The quantity of oil produced is estimated at 15000 stbo/day which will require a separator that has the capacity of hold a liquid rate of about 20000 stb/day. The developmental wells are subsequently increased to achieve a water cut of 90-95% with more recoverable oil within the 15-year field life. This developmental plan is also cost effective as drilling more wells means more capital expenditure.

Integrated Static and Dynamic Study to Determine Optimal Infill Potential of A High Water-cut Oil Field in Sudan

2010 ◽  
Author(s):  
Limin Zhao ◽  
Yang Liu ◽  
Dezhi Bian ◽  
Xianghong Wu ◽  
Wei Li ◽  
...  
Keyword(s):  
High Water ◽  
Oil Field ◽  
Dynamic Study ◽  
High Water Cut ◽  
Water Cut

Pre-Warning and Decision Making of Water Breakthrough for Higher Water-Cut Oil Field

2011 ◽  
Vol 347-353 ◽  
pp. 688-693
Author(s):  
Han Qiao Jiang ◽  
Shuo Liang Wang ◽  
Yuan Zhang
Keyword(s):  
Decision Making ◽  
Early Warning ◽  
High Water ◽  
Oil Field ◽  
Warning Signs ◽  
Water Shutoff ◽  
Profile Control ◽  
Single Well ◽  
High Water Cut Stage ◽  
Water Cut

Major domestic oil fields have entered the period of high water now, however, choosing timing of profile control and water shutoff is always delay, Mostly have to wait until after the adoption of dynamic degradation. This article introduced the concept of early warning that is widely used in military and economic fields to profile control and water shut-off decision-making in high water-cut stage. Combination of actual situation of water shut-off decision-making, Presented a strong adaptive set of Warning signs of indicators, on the basis of the analysis of variation in the warning sighs of indicators, this paper proposed early warning model and processes of profile control and water shut-off. The model not only can give the current degree of a single well, but also can forecast the future degree of change in a period of time, so this modle could provide an effective basis for water shutoff and profile controle decision-makers.

On the Feasibility of Applying Electric Field to Increase Oil Recovery in Old Oil Field

2014 ◽  
Vol 900 ◽  
pp. 677-680
Author(s):  
Chun Hong Nie
Keyword(s):  
Electric Field ◽  
Oil Recovery ◽  
Water Injection ◽  
High Water ◽  
Oil Field ◽  
Thin Layers ◽  
Stable Yield ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut

This paper has discussed the characteristics, roles, feasibility and obvious effects of the technology by applying electric field to enhance oil recovery when the oil field is in high water cut stage and super high water cut stage. In view that most oil wells in old oil field have entered into the super high water cut production, the remaining oil in the main reservoir is in fragmented distribution with poor results of water injection and new reserves of oil mostly have a low penetration rate and are thin layers of poor physical properties, the use of the direct current field in period of high water cut is the best policy to achieve high and stable yield and is fairly promising.

Application of Multivariate Regression Method in the Prediction of Oilfield Development Indexes

2014 ◽  
Vol 1010-1012 ◽  
pp. 1643-1649
Author(s):  
Qi Li ◽  
Ming Qin ◽  
Hong Bo Wang ◽  
Ji Cheng Zhang
Keyword(s):  
Multiple Regression ◽  
High Water ◽  
Yield Component ◽  
Regression Method ◽  
Oil Field ◽  
Water Flooding ◽  
Development Zone ◽  
Development Index ◽  
Field Development ◽  
Oilfield Development

Currently most of our oil fields have entered the extra high water cut stage. Accurate prediction of field development dynamic is the foundation of the reasonable, efficient, sustainable oil field development. Prediction of oilfield development index have varieties of methods ,including the law of diminishing water flooding Union law solution, yield component method, multiple regression and so on. In this paper, we take xingnan development zone eight to twelve district extension well network development index prediction as an example, introduces the application of multiple regression method in the prediction of reservoir indicator.

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