Combining Innovative Technologies To Maximize Scale Squeeze Cost Reduction

Bourne, H.M.; Booth, Steven L.; Brunger, A.

doi:10.2118/50718-ms

Cited by 38 publications

(7 citation statements)

References 13 publications

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“…This finding has been suggested before for this and other NIA chemicals. 10,16,21 The coreflood data were used to generate an adsorption isotherm that was later used to help design the initial field squeeze treatments of this product at Milne Point. This process has been described by other workers.…”

Section: Laboratory Resultsmentioning

confidence: 99%

Development and Deployment of a Scale Squeeze Enhancer and Oil-Soluble Scale Inhibitor To Avoid Deferred Oil Production Losses During Squeezing Low-Water Cut Wells, North Slope, Alaska

Jordan¹,

Graff²,

Cooper

2000

SPE International Symposium on Formation Damage Control

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe paper outlines the experimental work that has been carried out to develop an effective treatment strategy for production wells, specifically those with electrical submersible pumps (ESP's) that suffered significant performance impairment at water cuts of less than 5% due to carbonate scale deposited within the ESP's. These Alaskan production wells had been treated for a couple of years using aqueous based scale inhibitor squeezes. Many of these treatments resulted in a significant 10% to 20% reduction in the oil production rate following the squeeze. The damage mechanism was investigated by coreflooding and revealed to be a combination of water block and relative permeability effects. Following the damage investigation coreflood, a second study was undertaken to investigate a chemical treatment to remove the damage already present within the near well bore and prevent further deposition of scale. The result of this test program was the development of a treatment strategy which used a solvent package followed by an oil soluble scale inhibitor. Field results of this type of treatment suggest that the wells treated with this chemical system did not suffer any reduction in oil production rate and were effectively protected from carbonate scale. Wells that had been damaged by the previous aqueous treatments could be stimulated and the lost oil production recovered. Reference is also made to the development of an improved aqueous based squeeze treatments for the treatment of higher water cut wells.

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Section: Laboratory Resultsmentioning

confidence: 99%

Development and Deployment of a Scale Squeeze Enhancer and Oil-Soluble Scale Inhibitor To Avoid Deferred Oil Production Losses During Squeezing Low-Water Cut Wells, North Slope, Alaska

Jordan¹,

Graff²,

Cooper

2000

SPE International Symposium on Formation Damage Control

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“…The various techniques that may be adopted to meet the challenges of scale control may be divided into four principal categories, as follows: 1) Selection of injection fluid source 2) Chemical inhibition 3) Chemical/mechanical remediation 4) Flow conformance Details of all these various techniques are given elsewhere. 1,[13][14][15][16][17][18][19][20][21][22][23][24][25][26][27][28][29][30] Where Does Scale Form?…”

Section: Or Caso 4 ) (Equation 2)mentioning

confidence: 99%

Integrated Field Development for Effective Scale Control throughout the Water Cycle in Deep Water Subsea Fields

Jordan¹,

Mackay²

2005

All Days

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractScale control in produced fluids as water follows the cycle of injection, production, processing and reinjection in oil production facilities is, in many cases, critical to the effective production of hydrocarbons in a safe, economic and environmentally acceptable manner.This paper focuses on the challenges to scale control in deepwater reservoirs, and describes the scale control measures that are designed into the field development plan based on the integration of reservoir simulation, completion design technology and production chemistry. Emphasis is placed on the need to consider the full life cycle of the field, considering a range of development scenarios, such as water flooding with seawater, desulphated seawater, produced water re-injection, aquifer water injection and primary depletion.Advanced fluid flow and reaction calculations that account for in situ scaling reactions and the impact on the produced brine chemistry are used to provide data to refine the economic models used to identify the optimum scale management technologies. The various functions that must be carried out for effective scale management at the CAPEX and OPEX phase are outlined.The paper clearly demonstrates how, by using an integrated team that includes personnel drawn from operating company, chemical service company and research institute backgrounds, a multi-disciplinary approach may be used to integrate engineering and chemical solutions to effectively arrive at the most economic scale control programme for these challenging fields.

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“…The various scale management techniques are also given elsewhere 1,[13][14][15][16][17][18][19][20][21][22][23] , as are the particular considerations for deepwater systems [24][25][26] .…”

Section: Scale Riskmentioning

confidence: 99%

Integrated Risk Analysis for Scale Management in Deepwater Developments

Mackay¹,

Jordan

Feasey

et al. 2004

All Days

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractDue to the increased cost of scale management in subsea compared to platform or onshore fields, and because of the more limited opportunities for interventions, it is becoming increasingly important to carry out a risk analysis process for scale management as early as possible in the field development plan. This process involves identifying the potential scale risks, and analysing and comparing the options available for managing those risks.This paper discusses how this risk analysis process should be carried out, with a strong emphasis on the need to integrate all the available production chemistry and reservoir engineering data. To demonstrate this process, an example from a development complex, which lies in >400 m (>1300 ft) water depths offshore West Africa, is used. The process has involved the following steps:Analysis of available brine samples to identify maximum scaling potential. Laboratory testing of available scale inhibitors to identify chemistry best suited to this system. Study of analogue fields to identify scaling risks in these fields, and how these risks have been managed, with implications for fields currently being studied. Modification of full field reservoir simulation model to predict seawater breakthrough and duration of seawater production, to identify when, for how long, and using how much inhibitor the wells would require squeeze treatments to control scale. This process involves using flow profiles derived from the reservoir simulation model, and applying them in a near well squeeze simulator to predict treatment performance to minimum inhibitor concentration measured from laboratory studies. Well-by-well analysis of predicted seawater production profiles and total water production rates to identify

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Combining Innovative Technologies To Maximize Scale Squeeze Cost Reduction

Abstract: This paper was prepared for presentation at the 1999 SPE International Symposium on Oilfield Chemistry held in Houston, Texas, 16-19 February 1999.

Cited by 38 publications

References 13 publications

Development and Deployment of a Scale Squeeze Enhancer and Oil-Soluble Scale Inhibitor To Avoid Deferred Oil Production Losses During Squeezing Low-Water Cut Wells, North Slope, Alaska

Development and Deployment of a Scale Squeeze Enhancer and Oil-Soluble Scale Inhibitor To Avoid Deferred Oil Production Losses During Squeezing Low-Water Cut Wells, North Slope, Alaska

Integrated Field Development for Effective Scale Control throughout the Water Cycle in Deep Water Subsea Fields

Integrated Risk Analysis for Scale Management in Deepwater Developments

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