SPE 165044 Electrical Heating in Surface Facilities_Artificial Lift Americas 2013

7/28/2019 SPE 165044 Electrical Heating in Surface Facilities_Artificial Lift Americas 2013

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SPE-165044-MS

Optimizing the Efficiency of Artificial Lifting Systems in the Production ofHeavy Crude, by the Use of Electrical Heating in Surface FacilitiesM. G. Jaimes, SPE, J. Durn, SPE, and F. E. Sanabria, Ecopetrol S.A; and R. Dorado, Corporacin Natfrac.

Copyright 2013, Society of Petroleum Engineers

This paper was prepared for presentation at the SPE Artificial Lift Conference-Americas held in Cartagena, Colombia 21-22 May 2013.

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 beenreviewed 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, itsofficers, 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 repro-duce 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.

AbstractUntil recent years, heavy oil was rejected as an energy resource for the inconvenience and costs associated with its production,

but today, with the gradual depletion of deposits of light oil, its reserves have attracted the interest of oil companies andgovernments around the world. Estimated reserves of heavy oil in the world equal to three times the combined reserves ofconventional oil and gas exist and are the safest source of energy in the immediate future of humanity.

One of the major drawbacks in the production of heavy oil in mature fields, is the low efficiency of artificial liftingsystems, which is presented by the high frictional pressure losses that are handled by the system (subsurface equipment andrecollection facilities), which occurs as a result of the high viscosity and / or direct emulsions (water in oil) of the producedfluids (viscosities above 500 cp.).

As an alternative to improve the efficiency of artificial lifting systems in the production of heavy oil in Colombia, from

reducing viscosity of the produced fluids, was visualized the selection, evaluation and application in surface facilities of thetechnology of electrical heating., to ensure adequate conditions of extraction and recollection that will maintain optimal levelsof production and release of lower-producing areas with higher API gravity.

This study presents a detailed technical and economic evaluation of the application of electric heating in surface facilitiesto optimize the efficiency of artificial lift systems in the production of heavy oil in fields operated by Ecopetrol in Colombia,including: nodal analysis to determine incremental production, evaluation of technical and economic benefits (net presentvalue). This paper presents the application results in the Tisquirama field.

Finally, the main findings, conclusions, recommendations and field results obtained in this study are presented and amongwhich are:

1. Increased of the efficiency of the artificial lifting system in 100%.

2. Increased of oil production in 100%.3. Unlock and producing of lower zones of high API gravity.

IntroductionWith the decreasing of the global supply of light and medium oil, heavy oil deposits become important, and the oil

companies will inevitably begin to consider the costs and logistics to develop these fields. The oil industry has felt thegreat need to develop the fields of heavy and extra heavy oil, and that 66% of oil reserves in the world corresponds tothis type of deposits (USGS, 2009). The Andean countries have a major portion of the world's heavy oil deposits. Theyalready operate successfully in the Orinoco Belt of Venezuela, and Colombia in particular is actively promoting the op-

portunity.In heavy oil production come some challenges, and one of them is mainly the low efficiency of artificial lift systems by

high viscosities and therefore higher friction losses that are handled in the system, which does not allow extraction capabilitiescommensurate with the volumes of contribution from the reservoir to the wellbore. Another disadvantage is present in the

transportation of production from the wells, due to the increase in the viscosity of the oil (C. Curtis et al, 2002) given by the


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2 SPE-165044-MS-MS

decrease of temperature. These are some proven technologies which have been developed to solve this problem: the injectionof steam, the dilution using naphtha, chemical for reduction of viscosity and the electrical heating in the down hole andsurface Facilities(E.H.S.F) among others.

E.H.S.F. has shown excellent results worldwide, with more than 600 applications, it is a relatively inexpensive technology(with an average incremental cost of between 1-2 U.S. $ / barrel), it is easy to implement and is a technological alternativeclean, safe and environmentally compatible, making was viewed as a special tool to implement in wells with high fluid and

low efficiency of artificial lift system.

This paper presents the technical and economic advantages of implementing the EHSF in the Tisquirama-Z Well, a specificcase in Colombia, which can be used as a reference point to implement this alternative technology in other heavy oil fieldswith similar problems.

Conceptual StudyThe major use of electrical heating tracing on the surface began to take hold in the full development of the oil industry in theearly 50 'when the need arises to find a technically and economically viable tool in situations where steam could not be use orwas impractical. The first applications typical of electrical heating tracing system were for lines of pipeline (> 200 ft),Carrying oil, asphalt and waxes (Stanberg C. et al).

The tracing system of electric heating has been developed over time and there are several patents and applications in

different areas of the oil industry (See Figure 1): Production, Petrochemical, Refining, Transportation, etc.

Figure 1- Electric heating tracing applications in the petroleum industry

Electrical Heating in Surface Facilities (E.H.S.F)Is an Electric Heating System used in pipes for transporting viscous fluids sensitive to temperature changes such as heavycrude oils and / or paraffinic.

Typical components of E.H.S.F. In Figure 2 can see the components of an E.H.S.F. The main components are: Transformer,Control Panel, thermocouples, tube heat generator, electrical conductor, insulation and mechanical protection element.

Figure 2- Typical Components of E.H.S.F.

Cryogenic base tank Tank Heating System

Ramp HeatingConventional Heat Tracing

Pipe, Vessel & Tank

Heating System

Heat Tracing Power

Distribution System

Trac Loc

E.H.S.FLong Lines

Heating

Downhole

Heating

Pipeline

Thermo-couple

transformer

Control Panel

Insulation

External

Proteccion

Heat Tube

Electrical

Conductor


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SPE-165044-MS-MS 3

The E.H.S.F. System consists of an insulated electric cable, installed inside a ferromagnetic heating pipe connected to thepipeline. The insulated wire is connected to the heating pipe at the far end, and an AC voltage source is connected between theheating pipe and the insulated wire at the point of electrical connection. AC current flows through the wire, returning by theinner surface of the pipe.

The E.H.S.F. System is electrically safe and produces heat in the ferromagnetic pipe thanks the effect of two electricalphenomena very known: Skin Effect and Proximity Effect. These phenomena are responsible that the current flowing in the

heating pipe is concentrated in the inner surface.

Current concentration is so complete that virtually there is no measurable voltage on the external wall of the heating pipe.The heat is also generated due to the resistance heater tube and the electrical cable, and by eddy currents and hysteresis in theheating pipe. From the moment the heating pipe is secured to the process pipe and fully integrated within the thermalinsulation, heat is efficiently transmitted to the process pipe (Figure 3).

AC voltage generates a current in the conductor which returns through the inner surface of the heat pipe. Virtually there isno measurable voltage on the outer surface of the heat pipe, allowing that the pipe system can be grounded.

Figure 3- E.H.S.F. Operating Principle

Technical Benefits of E.H.S.F. Implementation.

1. Viscosity decrease in the flow lines, which is same as decrease pressure loss in system.2. Increased of efficiency and reliability of artificial lift systems.3. Increase of capacities of extraction of artificial lift systems.4. Increase of volumes of heavy oil production.5. Prevention and remediation of hydrate formation and paraffin.6. Reduction and / or elimination of the chemical injection or circulation of hot oil and the respective infrastructure.7. Reducing costs associated with transportation of crude oil.

Technical Advantages of E.H.S.F. implementation.

1. Installation Quick and Easy (10 days).2. Deferred production is not generated; there is no need to stop the well.3. Clean and Safe Technology.

4. Average cost per incremental barrel of 1 to 2 U.S. $ / barrel. 5. The circuit is encapsulated within resistant heating pipes and steel boxes.6. Technology has a monitoring system that includes temperature sensors.7. Circuit length of up to 25 kilometers with an electric supply point single.8. High Temperature Exposure (up to 500 F).

E.H.S.F Limitations.1. It requires a special transformer.2. It is not practical in pipe fittings such as valves and flanges.

Differences between E.H.S.F. and Other Methods. Table 1 shows the differences between the electric heating and othersimilar methods used to reduce the viscosity of heavy oil both in the downhole and surface, which shows the advantages ofE.H.S.F compared to other technologies.


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Table 1. Comparison of E.H.S.F. vs. Other Methods.

BenchmarchingIn literature are reported more than 300 applications in wells (Downhole Heater) and more than 600 applications ofE.H.S.F, Figure 4 and 5.

Figure 4- Historical Cases of application of E.H.S.F

Figure 5- E.H.S.F Application Statistics.

Figure 6 presents the results of increased production by the application of E.H.S.F. in heavy oil producer wells.

E.H S.F vs Hot

Oil

E.H.S.F vs

Naphtha Dilution

E.H.SF vs

Chemical

Additives

E.H.S.F vs

Steam Injection

E.H.S.F vs Hole

Heating

Eliminates or reduces

paraff in dow ntime

No compatibility test

requiered

No Negative ef fect on

ref ining catalyts

No steam boiler

requiered

No production decrease

due to increased gas

phase

No formation damage low er cost No toxic No steam lines to theproduction wells

Lower pow er consumption

No multiple oil tretmentNo adittional injection

f lowlines required

No injection

equipment required

No f reezing

problems during

shutdow n

Low er cost

Conventional

operating and

maintenance

procedures

No increase pressure

due f lammable

materials

No safety issues

w ith from leaks

No production interrumption

by installation


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SPE-165044-MS-MS 5

Figure 6- Results of application of E.H.S.F.

Selection Criteria for application of E.H.S.F.

1. Wells with paraffin precipitation in the subsurface equipment and recollection system.2. Lower efficiency of artificial lift system in heavy oil wells (high level of fluid).3. Wells producer of oil with gravity less than 24 API, to avoid reduction in the volume of crude. 4. Zone producer with minimum water saturation or open intervals far enough of the water-Oil Contact.

Case Studies: Tisquirama-Z Well

Base Case. Tisquirama Oil Field is located in the Basin Middle Magdalena Valley, an elongated region in a North - South,between the Eastern and Central Cordilleras of the Colombian Andes (See Figure 7). The Tisquirama-Z well was drilled onJune 11, 2008 and initially completed on 20 June of that year in the sands Lisama B and Lisama C, which were fractured.Later on July 18 of that year was completed in the sand Lisama A. On June 26, 2008, the well remained in mechanical

pumping with initial production of 140 BPD and a water cut of 35%, and the 14 October of that year changed the artificial lif tsystem to Electric Submersible Pumping (ESP) with a production of BPD 160 and water cut of 0.2%.

Figure 7- Location of Tisquirama Oil Field.

The Lisama A formation, Lisama B and Lisama C have the following characteristics:

Lisama A: heavy oil (12 API), Top: 7660 ft, reservoirpressure: 3311 psi.

0

100

200

300

400

500

600

700

Colombia 2 Venezuela 1Venezuela 2

BOP/D

BEFORE

AFTER

0

5

10

15

20

25

Colombia 1 USA

BO

P/D

BEFORE

AFTER


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Lisama B: heavy oil (17 API), Top: 7874 ft, reservoir pressure: 1780 psi.

Lisama C: medium crude (23 API), Top: 8140 ft, reservoir pressure: 1341 psi.

Before the implementation of E.H.S.F technology, the Tisquirama-Z well produced only of the Lisama A formation (165BFPD with a cut of 15%, oil 12 API), due to blockage of Lisama B formation and Lisama C by high levels of fluid thatwere maintained at the well (reservoir pressure less than the flowing bottomhole pressure, Pwf). This situation occurred for thelow efficiency of artificial lift system, which did not allow increasing the extraction capacity to reduce the high levels of fluid

present in the well.Added to above, by the high viscosity of the oil produced (12,000 cp at 122 F) were generated high pressure losses from

downhole to the recollection and treatment station (THP of 215 psi, average), which forced the adequacy of wellhead facilitiesto mix the oil with other neighboring wells with higher API gravity, thus ensuring the transport of this heavy fluid to therecollection and treatment plant, but results in decreased pressure losses in the system were not significant.

Technical analysis of E.H.S.F implementation in the Tisquirama-Z WellImplementation of E .H.S.F. According to the conceptual level study and the evaluation matrix on technologies for reducingviscosity, the E.H.S.F technology was selected as the best option.

Implementation of E.H.S.F. in the Tisquirama-Z well, was held on November 8, 2011, becoming the first implementationof this technology at the level of surface facilities of a heavy oil well in Colombia, which creates high expectations for otherwells Tisquirama field and other fields with similar problems.

After the implementation of E.H.S.F. in the Tisquirama-Z well is present an increase of production of Total fluid andwater, from 165 to 335 BFPD and 25 to 60 BWPD respectively, from Lisama A formation and Lisama B. The increase ofwater was produced possibly by a coning caused by the proximity of the oil-water contact at producers intervals of the LisamaA formation. The coning effect is evident when performing the analysis of graph Chan, where you can observe a decrease inthe line of the derivative of the water-oil ratio (WOR) and the respective increase of WOR, See Figure 8.

Figure 8- Chans Graphic, Tizquirama-Z Well.

Diagnostic Events Diagram. Figure 9 shows the Diagnostic Events Diagram occurred during the history of the Tisquirama-Zwell, from the initial completion until after the implementation of E.H.S.F. The Y axis shows the depth and the production,and the X axis shows the corresponding event date. As can be seen, after the implementation E.H.S.F of is present a markedincrease in total fluid production in response to the electrical heating of flow lines from the wellhead Tisquirama Z to therecollection station (82 F increased to 171 F). This heating generated a decrease in viscosity of >12.000 cp to 2000 cp,which in turn decreased the loss of pressure in the system (THP of 31 psi, average.), thus improving the efficiency of ArtificialLifting System. On June 23, 2012, shows stable water flow and a significant decrease of oil flow.

1E-08

0.0000001

0.000001

0.00001

0.0001

0.001

0.01

0.1

1

10

100

WOR,

WORDeriva

tive

Time (days)

WOR

WOR'

TRACING

50 per. media mvil (WOR)

2 per. media mvil (WOR)

50 per. media mvil (WOR')

Lineal (WOR')

Water Oil Ratio

PosibleConificacin


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SPE-165044-MS-MS 7

Figure 9- Diagnostic Event Diagram of Tizquirama-Z Well.

Figure 10 shows the Behavior of the fluid level and THP pressure in the Tisquirama-Z well, before and afterimplementation of E.H.S.F technology. It can be seen as immediately after the implementation is presented a drastic decreaseof the friction pressure loss due to decrease of the viscosity by heating of the fluid. For stabilize the bsw, On June 23 of 2012and due to increasing water cut, it was decided to decrease the extraction capacity, resulting in an increase in fluid level andthe blocking again Lisama B zone ((Pwf reaches value of 2130 psi to pmp).

Figure 10- Behavior of the Fluid Level and THP, Tisquirama-Z well.

Nodal analysis-IPR. Consideration was given to two cases to analyze the behavior of IPR curve in time:

Case 1: Initial condition before implementing the system E.H.S.F.

Case 2: Condition one month after implementing the system E.H.S.F.Assumptions. To make the production modeling of the Lisama A formation, "Lisama B" and "Lisama C, the following

assumptions were made:

3000.0

3500.0

4000.0

4500.0

5000.0

5500.0

6000.0

6500.0

7000.0

7500.0

8000.0

8500.0

9000.0

Jun-08 Dec-08 Jul-09 Jan-10 Aug-10 Feb-11 Sep-11 Apr-12 Oct-12

0

25

50

75

100

125

150

175

200

225

250

275

300

325

350

375

400

425

450

DEPTH

ft

PRODUCTION

DIAGNOSTIC DIAGRAM TISQUIRAMA ZOIL

WATER

FLUID

PRODUCER GUNS

HIDRAULIC FRAC

PUMP EXCHANGE

ROAD PUMP BES

R.P. BES

MIX Z,Y

MIX Z,W

MIX Z,X

TRACING

2400.0

2900.0

3400.0

3900.0

4400.0

4900.0

5400.0

5900.0

6400.0

6900.0

7400.0

7900.0

8400.0

8900.0

6 /1 /2 00 8 1 2/ 18 /2 00 8 7 /6 /2 00 9 1 /2 2/ 20 10 8 /1 0/ 20 10 2 /2 6/ 20 11 9 /1 4/2 01 1 4 /1 /2 01 2 1 0/ 18 /2 01 2

0

25

50

75

100

125

150

175

200

225

250

275

300

325

350

375

400

FLUIDL

EVEL

ft

THP

THP & FLUID LEVEL BEHAVOIR VS TIME TISQUIRAMA Z THP'

PRODUCER GUNS

FRAC

PUMP REPLACEMENT

EXCHANGE ROADPUMP BES

B.M BES

MIX Z,Y

MIX Z,W

MIX Z,X

TRACING

FLUID LEVEL


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8 SPE-165044-MS-MS

1. Cross flow not presented due to the high viscosity of oil of the Lisama A" formation.2. Production modeling for each of the zones separately.

Case 1.For the initial condition (before installing E.H.S.F), modeling was performed only in the area that provides fluid, is tosay, Lisama A. (see Figure 11 and Figure 12).

Figure 11- Initial condition before E.H.S.F.

Figure 12- Lisama-A Modeling before E.H.S.F.

lisamaLisama A

Lisama B

Lisama C

Reservoir Pressure = 3311, psi


Reservoir Pressure= 1341, psi

Initial Condition without TracingFluid Level

Pwf (Lis A) = 1768, psi

Pwf (Lis B) =1852, psi

Pwf (Lis C)= 1890, psi

TISQUIRAMA Z, LISAMA A

P 3311, Pwf 1768, API 12, GOR 211, BSW 15, Ko 513

Production Index AOF C-coefficient n-coefficient

(STB/day/psi) (STB/day) (STB/day/psi2n)

0.1135 250.4 Vogel

0

900

1800

2700

3600

Downhole

FlowingPressure(psia)

280210140700Total Production Rate (STB/day)

S = 1.41

165

1768


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SPE-165044-MS-MS 9

Case 2.For the condition after installing E.H.S.F, modeling is performed separately for each of the areas contributing fluid tothe well, is to say, Lisama A and Lisama B.(See Figure 13, Figure 14 and Figure 15).

Figure 13- Final condition after E.H.S.F.

Figure 14- Lisama-A Modeling after E.H.S.F.

lisamaLisama A

Lisama B

Reservoir Pressure= 3311, psi


Presin del yacimiento = 1341

Final Condition with Tracing

Lisama C

Pwf (Lis A) = 1372 psi

Pwf (Lis B) = 1437 psi

Pwf (Lis C) = 1446 psiReservoir Pressure = 1341, psi

Fluid Level

TSQ 9, LIS A

P 3311, Pwf 1372, API 12.2, GOR 211, BSW 25.5, Ko 513


(STB/day/ps i) (STB/day) (STB/day/ps i2n)

0.1135 250.4 Vogel

0

900

1800

2700

3600

DownholeFlowingPressure(psia)

280210140700Total Production Rate (STB/day)

S=1.41

165

1768

196

1372


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10 SPE-165044-MS-MS

Figure 15- Modeling Lisama B after E.H.S.F.

Economic Analysis

Economic Evaluation Scenari os. Some premises have been considered in order to perform the economic evaluation of theimplementation of E.H.S.F in "Lisama A" and Lisama B formations:

Revenues gained by production increase are due to production acceleration during 15 months equivalent 81 179BOPD.

Decline production rate before the implementation of E.H.S.F was a 1.14% per month.

Scenario 1.

Implementation of E.H.S.F Technology. This scenario considers an increase in real production by accelerating the sameduring fifteen months, with total cumulative production (basic + incremental) of 81,179 BOPD. The fifteen monthscorrespond to the time since E.H.S.F technology was implemented to date in that was writing this article. Under this condition,revenues are linked to oil production and energy savings of the Artificial Lifting System, and expenditures are associated withthe cost of implementing of the tool and the monthly energy expenditure generated by E.H.S.F technology (Figure 16) .

The following are additional benefits which have not quantified in the economic model, but are equally important tounderline:

1. Increasing the useful life of Artificial Lifting System, taking into account working at conditions of operation (P,T) less severe.2. Reduced transportation costs and improving the conditions of treatment, taking into account that oil enters at

much higher temperature to the recollection and treatment station. (Before E.H.S.F: 82 F, after E.H.S.F: 171 F).

3. Production of crude of better quality API, by decreasing the flowing bottomhole pressure, Pwf, and allow fluidinput from the "Lisama B" formation.

TSQ 9, LIS B

P 1780, Pwf 1437, API 17, GOR 263.7, BSW 0, Ko 89.73


(STB/day/psi) (STB/day) (STB/day/psi2n)

0.4373 428.9 Vogel

0

600

1200

1800

2400

DownholeFlowingPressure

(psia)

5003752501250

Total Production Rate (STB/day)

S=0.47

137

1437


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SPE-165044-MS-MS 11

Figure 16. Economic Anaysis of Scenario with E.H.S.F.Scenario 2.

Base Case: without implementation of E.H .S.F technology. This scenario includes the well production under conditions

without implementing E.H.S.F technology, given a forecast of production at a rate of decline of the basic curve of 1.14% permonth and initial water cut of 15%, 26 months delay to recover the same oil production (81,179 BOPD). Incomes areassociated with this production forecast of the basic curve of the Tisquirama-Z well (Figure 17).

Figure 17. Economic Analysis Scenario without E.H.S.F.

Economic Evaluation Resul ts. For scenario 1, the NPV is U.S. $2,104,452 while for scenario 2, the NPV is U.S. $ 2,034,287.This indicates that E.H.S.F tool installed in the Tisquirama-Z well, has generated profits of U.S$ 70,165.

Conclusions.

Implementation of E.H.S.F system, evidenced a of fluid viscosity decrease in surface, which generates a reduction infrictional pressure losses throughout the system (downhole to the recollection and treatment station).

E.H.S.F technology implementation resulted in greater efficiency and reliability of artificial lifting system, creatingless severe operating conditions of pressure and temperature during production. (Decreased pump operatingtemperature of 380 F to 269 F and decreased THP of 215 psi to 31 psi).

A greater efficiency and reliability of Artificial Lifting System, allowed increasing capacity of extraction and

therefore total fluid volume produced. A greater extraction capacity of Artificial Lifting System, allowed reducing flowing bottomhole pressure, Pwf,

making the release of the "Lisama B" formation, which gave rise to production of better quality API.

Implementation of E.H.S.F technology made possible reducing transportation costs and improving treatment anddehydration of crude oil, given the temperature increase of the fluid (Before E.H.S.F: 82 F, after E.H.S.F: 171 F).

For the case of fouling water production, having a lower operating temperature of the pump may generate lessfavorable environments for the precipitation of inorganic deposits.

Implementing E.H.S.F technology does not require turning off the wells, thus deferred production is not generated.

E.H.S.F tool is clean and safe technology, which make it compatible with the environment and suitable to accomplishHSEQ regulations.

Implementation of E.H.S.F in the recollection and treatment station of Tisquirama field would have a significantimpact in reducing chemical treatment and transportation costs because it could eliminate the current dehydration

process constrains presented in this station.

Caso 1 : ELECTRICAL HEATING IMPLEMENTATION

TRACINGCOST

PRODUCTION REVENUE

0 MONTHS

15 MONTHS TO

RECOVER 81179 BOPD

Bnfc $$ (ENERGY SAVING)

ENERGY COSTS $$ (ENERGY OF ELECTRICAL HEATING)

Case 2: Without ELECTRICL HEATING

26 Months to recover

81179 BOPD

0 Months

Production Foerecast


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12 SPE-165044-MS-MS

Before implementing E.H.S.F system, is recommended to do an integral technical and economic evaluation (well-station), to observe and quantify additional benefits.

Technical and economic advantages found with the implementation of the E.H.S.F tool into the Tisquirama- Z well,can justify or enable their use, not only in other wells in the field Tisquirama but also in other heavy oil fields withsimilar problems.

In the case of producing intervals with proximity to the oil-water contact, is recommended to do an evaluation beforethe E.H.S.F technology implementation, to determine optimal production rates and thus avoid early water coning.

AcknowledgementThanks to Ecopetrol S.A for allowing us to publish these results and each of the professionals who contributed in one way oranother and made possible the completion of this article.

Nomenclature

AC = Alternating Current

BFPD = Barrels of Fuid Per Day

BOPD = Barrels of Oil Per Day

BPD = Barrels Per Day

BWPD = Barrels of Water Per Day

BS&W = Basic Sediment and Water

E.H.S.F = Electrical Heat in Surface Facilities

GOR = Gas/Oil Ratio

Ko = Oil Relative Permeability

NPV OR VNA = Net Present Value

Pwf = Flowing Bottom Hole Pressure

THP = Tubing Head Pressure

USGS = United States Geological Survey

WOR = Water/Oil Ratio

WOR = Time-Derivative of the WOR

API = American petroleum institute

References

1. Ando, M., And Takki, H., Application of the Sect Electric Heating System to Long Distance Pipelines; Comit Francais

Electrothermie, 9th International Congress, Pp. 1, October 1980.

2. Bailey, b., Crabtree, m., Tyrie, j., Elphick, j., Kuchuk, f., Romano, c., Roodhart, l., Water Control; Oilfield Review, Vol.12, Issue 1, pp.32-38, March, 2000.

3. Chan, K.S., Water Control Diagnostic Plots, SPE 30775 M-S, SPE Annual Technical Conference and Exhibition, 22-25

October 1995, Dallas, Texas.

4. Curtis, C. Et Al, Heavy-Oil Reservoirs, Oilfield Review, Volume 14, Issue 3, pp. 31, September, 2002.

5. Fisher, R.R., Direct Electrical Heating of Flowelines - Guide to Uses and Benefits, OTC 22631, pp.1-10, October 2011.

6. Koester,G., Pipe Heat Tracing With Electric Impedance Heating, Plant Engineering, Volume 32, No. 24, pp. 113116,

November 23, 1978.

7. Sandberg, C., Joseph, T., And Erickson, J., Heat Tracing of Piping Systems, Chapter B6, Pp. 242-251, November 1994.


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8. Sandberg, Szemat, W.E., Misenta, I. P., and Secco, G. Downhole Electrical Heating System Feasibility of Heavy Oil

Implementation in Offshore Congo, SPE 136857, Pp. 1-3, November 2010.

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