.- -.

- m ..........Socistyof PetroleumEngineers

SPE 26987

Producing Extra Heavy Oil from the Orinoco Be!t by Electrical SubmersiblePumping System - A Pilot TestR. Gonzalez and M. Reina”, Corpoven S.A.●SPE Mambar

C.W;W 1994 SUCie!y 0+ P.UO!,UA Englnew,, l.c.,..

This ww wia @&laTed !0, Pr<$e3m3~l-,Ke 111Lat. A. E4mniCarlbbOa” Pe”ok”m E.ww!F& COnfars”C4 hdd in B“.”., Akq. Arw”ti”., 27.29 WI 1994.

ABSTRACT

EIeaw”and extra-heavy oils have. !cmn traditionallyproduced using sucker rod pumpq. However, thisproduction method is inefficient\ highly energycorrsumin~ mrd the umtirl life of the equipment isabort. Therefore, other methods of artificial Iiihave to be evaluated, irr order to exploit the hemgoil resm-vea more efficiently and economically.

In this papiir, the results of a pilot teat &irrg”aneleztrieal submergible pump to produce extra-hea~oil (9.2 “AH) in the Orinoco Belt, EasternVene-zda, are presented. The ma@numpreductioo rate obtained was 1,170 BOPD (186M%), tibkh iS 700 BOPD (i i“i M3D] hiderthan the maximum rate obtained with sucker rodpumping in .&e .gune weil. NO diueni was used in ~this particular test.

The pumping efficiency obtained (37.7V.) indicate~that with a higher capaci~ pump, production ratesof up to 2,000 330PD (318 M3/D), without the useof diuent, can be achieved.

INTRODUCTION

The Orinoco Belt comprises aevemd massivesceumrdations of heavy and extra-heavy oilspamlleiirrg the rrorthem bank of the Orinoco River inthe southern flank of the Eastern Venezuela Basin.The API gravity of the oil ranges &o~. 6 to 160~1at surfice conditions and the oil vxscosity rangesffom 140 to 21,000 eerrtipoises at 140 “F “(6O“C).The average sand porosity is about 30~o and thepermesbfi~ ranges &om 1 to 12 darcies. Reservoirdepth ranges fkom 600 f~ (183 M) irr the SoUth to4,000 feet (1,219 M) along the northern border ofthe area.

Although, the earliest exploratory well was drilled irr1935, exploitation of the area did not begin untilIW19,when petrbleos de Venezuela (PDVW andita affiliates commenced an aggressive. explorationequrign.

Since its begirrnin~ the production method utilizedin the area haa been sucker rod pumping withd~uent. WM this method, production ratas of up to1,300 BOPD (207 M3/D) with 3..5 in (8.89 cm] “-pumps and 2,000 BOPD (318 M3LD) with 4.5 irr

785

2 PRODUCING RXTRA HEAVY OIL FROM THS ORINOCO BELT BY ELECTRICAL SLIBMSRGIBLE 26987

PUMPING SYSTEM - A PILOT TEST

(11.43 cm) PUMPScan be obtained. Nevertheless,the lifting capacity of these pumps is consideredlow, due to the high productivity index of the wells.Therefore, other production methods need to beevaluated to exploit the huge hea~ oil reserves ofthe OMoco Belt, more efficiently and economically.

Corpoven S.A,, an afHiate of PDVS~ hasaccumulated extensive technical experience usingElectrical Submergible Pumps (ESP) in Barinas andApure States, Southwestern Venezuela, where itproduces 27 MBOPD (4,292 M~/D) of mdlumgravity oils (22-26 “API) ffom 40 wells. The needfor a more efficient production method for theexploitation of its heavy oil areas motivatedCnqroven to evaluate the ESP” h the Orinoco Bek,Well MFB-1 59, which is completed in the U1,3sand (MPB-53 Reservoir), was then selected for thetest. The test was conducted in a period of one anda half months.

The test was made in three phases. In each phase,the following parameters were monitored: bottomhole and well head flowing pressures and inlet andoutlet pressure of the diluent injected to the pumpand to the flowing line. Aditionstly, formation fluidsamples were collected and sent to the laboratoryfor analyses. The well was tested for 24 hours foreach pump frequency. Irr this paper the results ofthis test are presented, as well as a brief descriptionof the reservoir’s rock and fluid properties and theoperating characteristics of the pump utikzed duringthe test.

ROCK AND FLUID PROPERTIES

The reservoir selected for the test was the MFB-53

(’fMP H-15) rwemoir, located irr the Bare Fieldof the Orinoco Belt (See F@re 1). This is thelargest. resemoir that has been discovered in theOrinoco Belt, to date. The dmcnsions of thereservoir are 23,’786 feet (7,250” M) Iorrg irr theNorth-South direetion and 34,448 feet (10,500 M)wide in the East-West diieetion, The average net oil

sand thickness of the reservoir is 75 feet (22.86 M),with a maxirnurn net oil sand thickness developmentof 174 feet (53 M). The estimated volume of oiloriginally @place is 1,950 MMSTB (3 10X106M3).

The petrophysical parameters of the reservoir areaumrnarized in Table 1. The average values for eachparameter are as follows Porosity = 30%, ShaleContent = 5%, Water Saturation= 17%, HorizontalPermeability = 10.6 darcies, Vertical Perrneabfity =5.3. darcies. There is no free gas, origimdly, presentin the reservoir.

Reservoir oil and gas samples were recombined irr-the l+oratory to reservoir conditions of pressureand temperature, 1,160 psi (7992 kpa) and 137 ‘F(58 “C), to obtain a solution gas-oil ratio of 106SCF/STB. A subsequent PVT enaIysis yielded anAPI Oravity of 9.2 “API and nn oil fomrationvolume factor of 1.073 RB/STB.

Using itatic bottom hole pressure surveys endpressure decline curves, it was determined that, atthe time of the evrduatiom the bottom hole pressureand temperature in well MPB-159 were 1,065 psi(7,334 Irk) and 137 W (58 “C), respectively. Theproductivity index (PI), at the stated conditions, wasestimated to be 3.86 BOPD/psi. PI and RPI curvesare shown in Figure 2.

“me average production rate is bigher than 400BOPD (64 M31D) per well and the totaleutmmdative production for the resewoir, in eightand a half years of prodoctio~ is as follows: 44.1MMSTB(7.0 MMSCM)of Oii, 5.4 MMSTB(0.86MMSCM) of water, and 38.5 MMMSCF (1,09. .. ...” “..MMSCM) of gas. It should be mentioned that,aproxirnately, 900/0 of the curnnmlative productionhas been obtained through the use of Cyclic StesrnIrjection.

786

I

3 .R GONZALEZANDM FMNA 26987

CIIAIZACTERITICSOF WELL MFE-159~,..——

Well Ml%-] 59 was drilled and completed ori@raUyin the U1,3 ~_d, wit~ open hole gravel pack irr1983. It was placed on production in 1985. Figure3 shows the location of the well in the reservoir.During its produ~ion Me, it had been equipped witha sucker rod pumping unit to M its productio~which had reached 1,200 BOPD (191 M3/D), earlyon,

In Deceniber 1991, 7,286 tons of ateant wereinjectedinto the well, at-ler which it was placed onproduction with 1,200 BOPD (191 M3/D). ByAugust 1993, its cunmndative production was 1.12MMST’B (178 MSCM). Three months prior to theevahration of the electrical submergible pump(September 1993], the average ~roduction rate hti”been 400 BOPD (64 M3/D),

F@rre -4. shows the actual wfdl’s completiondiagr~ which consists of 7 in .(17.8 cm) casing,3.5 in (8.S9 “cm) production tubii~ the electricalsubmergible pump whose wction port is “at 2,65rSfeet (808 M), the protection (housing), two 160 Hpmotors, and the bgtim hole pressure-temperaturerecorder. The weU had been gravel packed for sandcontrol. The type of cable used is REDALEAD cl)ffom REDA #lOJ. Additionally, a 1.25.irr(3. 18 cm)coiled tubing was installed, taped to the productionstring, in order to inject diluent ilom the surface tothe ayction end of the pump. Thu8, reducing tieformation crude viscosity for a more efficient pumpperformance.

PUMP INSTA”L-UTIONDESIGN

The installation design was performed taking intoconsideration the basic data shown in Table 2 andconsidering the foUowing factors:

-Pumps highly resistant to -d abrasion and hightemperatures.

f])REDATrademark

787

-Eksctric motors with additional horsepower to--—. .that reqmred by the desigm two 160 Hp units.

-Pumping efficien~ irr the order of. 51?/~according to the performance profile for theselected pump.

-Capable of handIing highly viscous heavy cntdes.

A design program was mn considering oilproduction with and without dduent. The results ofthe design program are sirown in Table 3. —.

The electrical submer@ble pump selected was of thetype GN-200 -540 Series - ARZtlJ, which has 107stages and is highly resistant to abrasion. Thepumping capaci~ at maximum efficiency (66%) is3,000 BOPD (477 M3/D) and at 50% efficiency it is1,500 BOPD (238 M3/D), at a frequency of 60 Ik.The pump perfomce profile is presented irrFigure5. Accor&mg to the design requiremerrta, the needsof the electric motor was 286 Hp, but due to safetyreasons two 160 Hp motors were sekcted instead.Aa to the transformer capacity, the design progmrrrindicated a 169 KVA, however a 390 KVAtransformer was installed, which ha8 a 480 voltsinput voltage and a 1,153 volts output voltage, with82.5 amps at 60 Hz in each motor. The bottom holepressure and temperature recorders were designedto work under maximum preswres and temperaturesof 5000 psi (34,450 kpa) and 500 “F (260 ‘C),respectively.

JWMNXITON PERFORMANCE

The evaluation test was conducted in three phases.which are discussed as foUows.

Frequency Variation from Wlgh to Low andDiluent Rates fromHigh to Low

Dm”ng this phaa~ which was considered as thestart-up and system adjustment stage, high dduentrates were used to guarantee trouble &ee operationin the handling of conventional crude by the pump.

(1)~A Tmde_k

4 PRODUCING EXTRA HEAVY OIL FROM THE ORINOCO BELT BY ELECTRICAL SUBMERGIBLE 26987PUMPING SYSTEM - A PILOT TEST

The l@lr initial fiequencics (up. to 70 I@ were

aPPfi~ as & s.sf@Ym~sure io the loading andmaximum displacement of the pump during start-up,although these were reached increasing theficquency step by step ilom 30 to 70 Hz. In thistlrst phase, diluent was injected at a rate of 1,590BID (253 M3/D) through the annular space betweenthe casing and the production string, due to the factthat it was not possible to irje@ dduent through thecoiled tubing, probably due to an obstruction or afkttcrrrrbrg of the 0.5 in (1.27 cm) tail pipe whilelowering it when completing the wel.

Under these conditions, and at a frequency of 70Hz, the production rate reached 570 BPD (91M3/D) of formation crude, wtile the pump handleda total of 2,160 BPD (343 _M3@) of diluted 19“API erode. The observed amperage waa 43amperes and the bottom hole conditions were 700psi (4,823 “kPa)and211 ‘F (99 “C).

The results of a ae~ond and third teats at 65 and 45H.q respectively, are shown in Tables 4 and 5. Itwas observed that during the evaluation at 45 Hzand with 700 BPD (111 M3/D),-the pump drainedthe entire diluent cohrnm above ii, after which at%lure occurred, causing the equipment to stop and ~.

the well to start flowing naturally at a rate of 1,000BOPD (159 M3fD) initially, to decrease later to 240BOPD (38 M3/D).’ The well produced naturally forthree days and had a bottom hole temperature of185 “F (85 “C).

Frequency Variation from Low to High WithoutDiluent

In this phase, with bottom hole conditions st.~~q .,.at 630 psi (4,34 1 k%,),201 ‘F (94 “C), and 15amperes, the low, ,~equency (35 Hz) teti”” WE ..,.performed, without dduent. A production rate of.684 BPD (109 M3/D) of 9.2 ‘API @avhy crudewas attained. The results of this test aresummarized in Tables 4 and 5.

Figure 2 shows a graph of bottom hole pressureversus productio~ for the 35 Hz teat, The well

Inflow Performance Relationship (IPR) curve is alsopresented on the mph. It can be seen that at thesame bottom hole pressure attained by the pump,the well irrtlow is between 1,500 (238) and 1,700BOPD (270 M3/D), while the pump was able to Man average of 1,100 BOPD (175 M3/D). Thismeans that with the pump installed the well iscapable of producing horn 65 to 70°% of the oilvolume provided by the formation.

Figure 6 shows the production rate versus tlequencycurve, At 65 Hz a sudden drop in the production isobserved. This was due to a drop in amperage from31 to 21 amps, halfway during the test. The drop inamperage was due to some. additional vohrrne of gasentering the pump, which was not present during therest of the teat.. The two points shown at the rightend of the graph, above and below the results for 70~ were obtained during tbe third phase of the.ewduation with diluent injection into the well.

During t~ a&md phase, diluent was injected in theflowline, at the wellhead, to improve the separationand treatment process at the flow station. Table 5shows the diierent rates of dhrent irjection.

Figure 7 shows the behavior of the bottom holetemperature irrder flowing conditions and thesurf@ temperature of the fluid mixture. Thediff~ence in temperature is also plotted againstcrude production. It cair be obaeryed ~at theternpe&e “irrcrca&s as the “production rateincreases. The difierencc in temperature tends todecrease”with increasing production, reaching 75 “F(24 ‘C) at 1,095 BOPD (174 M3/D). This lastpoint on the graph corresponds to the evaluationcarried out with diluent in.@ last phase. F@.rre 8showa the behavior of the bottom hole temperatureduring flowing conditions, where a difference of 34‘T (19 “C) is observed between the well flowingnaturally at 185 T (85 “C) aiid when it flowed atmaximum rate, at 60 J+@with a temperature of 219“F (104 “C). This last temperature was obtainedbecause both 160 Hp irotors “were dissipatingmoreheat at that condition,

788

.

5 R GONZALEZ AND M. REINA 26987

CmmtnrIt Freqrrmrcy with DiIuentin the Well

This last phase, or complimentary phase, wasper%ormedto observe the well’s production behaviorwith diluent injection at the bottom, but ordy afterthe well had atabtied with the ekctricalSubmergible equipment at low diluent rates. Duringthe fiat test in this phase, diluent was injected at a

rate of 223 BPD (35 M3/D), while the total fluidIi&d reached a rate of 1,189 BPD (189 M3iD) of11.7 “API diluted crude. Another teat carried outyielded 1,170 BPD (186 M3/D) with a dfluentinjection rate of” 506 ““-B/D (80 M3iD). Thus,obtaining a total Iiiig of 1,677 BPD (267 M~/D)of diluted 13..9“API crude. The results of these tetsare graphically presented in Figures 6, 7, and 8.

Table 6 shows a listing of the electrical parameters,both measured sod calculated. They include thehorsepower required by the pump, the horsepoweroutput by the motors, the calcdated amperage, thevoltage and capacity utilized by the transformer. Itcart be obsewed that the maximum’horsepower usedby the electrical submergible pump was 225 Hp andthe ma.xirmrmcapacity used by the transformer was178 KVA out of the 300 KVA available.

RESULT’S

Well MB-159 had” produced with a sucker rodpumping unit since its orighrd completion in 1983,The last production teat with the %cker rod, pumpwas 400 BOPD (64 M3/D), while during theevaluation of the electrical submergible pump itproduced an average of 1,100 BC)PD (175 M3~),which represents 700 additional berrela of oil perday.

The sample calculations made show that the volumeof gaa entering the pump was no more than 5°Athetotai volume produced at bottom hole cm-dtions,which justifies not installing downhole gasseparators. The well’s producing gas-oil ratiosduring the evaluation teat averaged 250 SCFL?H’B.

The electrical submergible equipment designconsidered a 50°4 pumping d%ciency in theperformance curve for the pump selected, over amaximum of 660/. efficiency and a capacity of 3,000BPD (477 M3/D) at 60 &, The production ratesobtained were compared to the prodrrc@on testresults at 60 m which was taken as the base case.These results abow that the rates obtain@ match thepump capacity at 40%0efficiency in the performancecurve. The curves described before (theoreticalproduction and pumping capacity at 40%’ e5ciency)match with rninimaI deviations up to 60 !++~tb $reobserved production cume, deviating later a? !55HZ ~~for the reasons explained before. Figure 10 showsthe behavior of the pumping capacities versustlequerrcies.

The described results show that fl.rture design ofelectrical submergible equipment to be used underconditions similar to those present in well MFB-I 59 -should consider designing installations with 40°%pumping efficiency, taken from the model’scalibration curves end type of pump which complieswith the expected capacity requirements.

F@re 5 presents the behavior eficiency curvescalculated utilizing information from the weU head,meimored production, pump horsepower, and therest ef6cienciea which were obtained from theproduction measured-pumping capacity ratio, atdifferent fiequerrcies. This ratio was used to correctthe ticiency due to the use of viscous crude againstthe capacity taken from the calibration curves forthe handling of water. The reaulta show a realaverage efficiency of 35°/0, while the maximumobtained was 37.70/0at 60 Hz.

Considering the results of the real pumpingeficiency applied to other pump models with highercapacities, it is estimated that production rates of upto 2,000 BOPD (318 M3113)can be attained. Table7 lists the different types of pumps and tbeiicapacities at 37,7% &ciency, correapondmg to theasme pump manufacturer. It is then conchrded thata model GN-2000 pump, which ia capable ofproducing 1,950 BOPD (310 M3/D) at 37.7%. _.

789

6 PRODUCING EXTRA BEAVY OIL FROM THE ORINOCO BELT BY ELECTRICAL SUBMERGIBLE 26981

PUMPING SYSTEM - A PILOT TEST

efficiency at 60”Hz, is the best possible choice for - The measured production was equivalent to 40%the conditions of the well under evaluation. of the installed pump capacity.

Figure 11 shows the different viscosity versus - .The obse~ed pumpbrg etliciencies were betweentemperature behavior curves for the different crudes 35 and 37.7%.produced (formation and dfluted) during theevaluation tests. The8e graphs simulate bottom hole - A GN-5200 (REDA) pump is required to produceas well as surface temperature of” the fluids at the maximum production rates expected flomdflerent viscosities, ranging tlom 1,100 SSU (23S well MFB-159.cps) at average bo~om hole temperature, to 1,800SSU Qj730 cps) at average surface temperature forfornmtion crudes having a gravity of 9,6 ‘API and avkcosity of 300 SSU (65 cps) at average bottom REFERENCEShole temperature and a viscosity of 900 SSU (195cps) at average Sufiace temptiature for a ,dditex+l 1.crude of 13.9 “API.

i20NCLUsIONs AND RECOMENDATTONS2.

- The maximumproductionobtainedwitout diluentat 60 Hz was 1,130 BOPD (180 M3/D) and1,170 BOPD (186 M3/D) at 70 Hz with dfluent 3.injection.

- The production from well MPB-159 increased 700BOPD (111 M3/D), going tlom 400 BOPD (64M3/D) with a sucker rod pump to 1,100 BOPD 4.(175 M3/D)witb an electrkd submergible pump,

- The maximum Iiimg capacity observed was 2,160BOPD (343 M3/D) of a diluted mixture of 19“AN Gravity,

- The electrical submergible equipment evahrated inthese teats was capable of producing behveen 65to 70% of the well’s potential..

-The heat dissipated by the two 160 Hp motorsincrea8ed the flowing bottom hole temperatureby 34 ‘F (19 ‘C).

American Petroleum Irrsiitute“Recommended Practice for” Sizing andSelection of Electric Submersible PumpInstallations”. API Recommended PracticeIIU(RF llU).

CentriMt-Hughes “The System”. Catalog1992.

Powerg M. L.: Yfbe Depth Constraint ofElectric Submersible Pumps”. Paperpresented at the 1993 SPE ElectricalSubmergible Workshop.

REDA “Submergible Pumps for thePetroleum Industry”. Catalog 1992.

-The maximum capacity reqtired for the 300 KVAtransformer irratakd was 178 KV~ or 59.3V. ofthe installedcapacity.

790

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SETS&

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—— .— _MF%ibi ill T<.* a.~ 9.0

MF51w $$ is 339 K*

MFs-tm 167 8,s -8 14.3

WB-1*7 1s1 32$ a., 1*S

w=M4s-333YJ 710 -444334.15

-usam4703i3 msu.o -

MFE=lwu3430cs@ 333.6s 197.5.34

MF6m3%31,1aa3E 433 mo .<s

.AvHuOEs.3 E,m $7d Ss5 .sm 97A .ta

TAsLE#2

WELL GASK2DATA

CASING 0!AA4ETER

TWIN OL&UEiER

PERFORAllONS

TOTAL DE Pm

PFUMMYVOL?AGE

STARC SO~OM HOLE PRESSURS

FLOWWG SOITOM HOLE PRESSURE

PROOUGlliSN RATE{BUILD UP lesT)

PROWC- INOSX

S4ST?OM HOLS TSNPERANRE

CRUOE OIL GRAVilY

WATER SPECS=fSGRAVTW

WATER CONTENT

GAs.ol I?Ano

BUSELE POINT PRESSURE

GAS s~auc GRAV31Y

W13_LHEAD PRESSURS791

TxZSLGMT.

3-w3-

38ar.37m

3233

460/450 VOLTS,

Wss PS3

Ss7 Psl

mm

3.86 S/nmsl

137F.

9.3. API

1.C4

5%

fw Pclm

6s4 PSI

.s7

*5Q Psl

i g..,~.’,’

TABLE #3

SPE2698?

PARAUETER

StmKe

amET

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MTAKZ-

. MO- POWER (HP)

-WJWAGS VOLTAQEAT CEH.?(VOLT8)

-p%&M?AtE

DILUENT

SC41ma

::2242s8Zr#

2347

40

.

TABLE #4M*URED vAmABLEs

FRmuENcYEVALUATIONcONomOiu WI AMP.

-... -—. ._9. mmwwx H1oHm Low u

SOTTOMHOLEDILUENT. : 30a 37

l.. FREQUENCY LOW TO lb

FLmmlNE. ,:lK

DILUENT W THE mU .

X-CONSTAMT FREQuENcY m 34DILUENTw THE BOTTOM 70 alHOLE AND IN WE FLOUUNC

WITHDILUENT

BOnnM HOLEMws5w(wll Tmqof)

~—

211E Zfs1$4 Its

870 Mt690 2M

34B03200

700*U8

2247

792

SURFACEPRES8URECOIITEMPIOFI——

7s 12670 1$470 i2c

. ...= .,. .=. ... .—...=,..., .“- . .. ..

TABLE MPilOWJCmON 7iATE V3 FREQUENCY

PUMP LmmGml)

spE26987 ,

.$%x’FRE-auwEVAUJAllON CONOITiONS WI

PRcaKnclN

RATE @ml

CiLUEMT IWO)

801T0M MOLE FISWIJNE

.— —

!s9

%

lAREwmL#J#lHHm”J~

HOLE

2,-7WQUEWY LCW lQ HIGHWUJENT w ‘?m FLOWJKZ

2I1O{ma

7W

mm

647W4M

7W.H4

4<9

3.. COWTANf FREWEW

Nilmhan., .,:.

-.

.

TABLE 9SELW7RKAL VARV@LES

10TALVC&lAGE

-

FREOUE!+SV - Pm

(w PUMP warm w.— ..—.— —

EvuuAnON —

f.-FREwL4cY Hwl 10 I.Ow

LNLWMTIN IKE SOTI’OM78 224 3?3 49.8 mmm w an 42.* 2s4s4S 8$ m W.* i7a

202130lf2

2.- FREWEWY Law ?0 W3H

—mM—

a.-mw’rw FREQIIEKY—fflmEs0170MlmLEMJolHE—

ImIlls

wIn

793

TABIA # 7

ELECTRICAL SUBMERGIBLE PUMPS CAPACITIES

S40 SERIES-i7EDA

FREQuENCY: 60 HZ

EFFICIENCY 40%

CRUDE OIL GRAV17Y: 9.6 “API

.MQwL

GN- 3200

GN- 4000

GN- 52OO

GN- 5+300

GN- 70M

GN-1OOOO

~

1170

1500

?950

2100

2650

3700

—

794

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TRAP B-15PILOT PROYECT

L ~ M,-.NJ,

FIGURE # 1, GEOGRAPHICAL LOCATION

!.* u“ .-

.-

TRAP B-15. BARE BLOCK

- PI

=’... ----

0 \0 500 1,200 1.500 2.OCO 2.500 3,01M 3.5W 4.000 4.500 .-

PRODUCTION RATE (t3/D)

FIGURE # 2. Pl, RPI ANO PRODUCTION PROFILE~~~ 795

IT’- --- .*.

W.......---*_ .#*.,. ,- /’---- \ “t. .’\\t..- -’:: /’” Z -- \

---------- - +

i, .!,.J # ,1 /’ ,:G-– --”., t, ,

/1, / \11. /----, t, i \ ,II, !,,11(1 \,%~.1

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l“’,%;

.’\ \{ii,;,

i,

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II

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FIGURE #3: LOCATION OF WELL MFB-159

A

)g USING 7- x 2,,,FI

I?IBING 1-1/2,,

u~

540 st?.IE6 ml+ “Am,, ?. 2630.,

Xnmm 540 m?.ms

— ,RwJmmP, 540 6?*IES

mmn m I 54.3 SEP.IrS

mm, v 2 540 SEXIE5

. __—,s, 540 SERIES A 2700,

m--.... ~‘TEm TALE 3-1/2”“.. - ‘ ,,

..- 1 ,81 .”..,.

.. 1! 1,1, , smm LINER 1-1/2.

. .

b

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. . . .,.’.

-“/.. . ....’... -. ... 16 x 25 GPAVEL

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P.E3222...,._ .,

FIGuRE # 4, COMPLETION DIAGRAM. WELL MFB-159

796

. .

, ~ ,. —..-, .,l

8PE26987GN32Q0 F’ulnP-sdosti -C+.?bdsnkan---

Reds Ri8u P51+u’=IICH C3irV8i stag= - et3200

540 Z6Pies -3500 m

E.m,,

. ..3,0., . .

.ml - W/m., -**

FIGURE # 5. PUMP PERFORMANCE CURVE

1.200 I .

ZQo

OL30 35 40 45 50 55 60 65 70 75

FREOUENCY (HZ)

FIGURE # 6. PRODUCTION RATE”vs FREOUENCY

797

-..=-’--:.

.,

~~ :nr$ ..: ““250

200

5[

-.

. .100 200 30.0. ..40.0 500 600 700 800 900 1,000 i.100 1.200 ?,300

0

. PRODUCTION. R.ATE (B/D)

FIGURE # 7, TEMPERATURE VS PRODUCTION RATE

.-.15010 10 20 30 40 50 60 70

FREQUENCY (HZ)

..in.;”$6987 “-

n.......“=+ BOTTOM HOI-2

A SURFACE

~ D, FFERE14CE

. 7.. ... . . . :. .-..

FIGURE # 8. BOTTOM HOLE TEMPERATURE. VS FREQUENCY

798

. .. .. .. .. . ..’

d-354045505560 6570 -75

FREQUENCY (HZ)

FIGURE # 9, PUMPING CAPACITY VS FREQUENCY

— ~..—-.~.=_.. .a ,,. . . ., ._ . . . . ..: .

I20

.:. ..SPE26987

- 66% EFF.

+ 50% EFF.

.* 40% EFF.

* EST. PROD.

+’+REAL PROD.

,..

. s..

El :“:..- CALCULATED

* REAL.

35 40 45 so .55 %0 65 70 75

FREQUENCY (HZ)

FIGURE # 10, PUMPING-EFFICIENCY” VS FREQUENCY

799

,. .—.. :’} ---,.;,.+.. -—.1Oo’.oa ---- .. .. ... .—. ... . . . . _.

10.00

Ic I

‘9+26987 “ --* .*. .-...., ==-,.-,.-.

- 9.3-API

- 9,6SAPI

*11 .7”API

+ 13.9-API

* 15.2dAPl

+ 19”API

* 22.5-API

.:.1 . .+ —.. . -.. .....-... *%...

100 110 120 130 140 150 160 170 180 190 200 210 220

TEMPERATURE ~F)

FIGURE ‘# 11. VISCO”51TV VS””FREQUENCY

—.

.’

800