SPE 169456 Assessment System First Gas Artificial Lift by ...

SPE 169456

Assessment System First Gas Artificial Lift by

Using (Coiled Tubing) in Punta de Mata District

Production Executive East

By, Jhonn Almendras, PDVSA EyP

Slide 2

Paper SPE 169456 Assessment System First Gas Artificial Lift by Using (Coiled Tubing) in Punta de Mata District Production Executive East • Jhonn Almendras

GEOGRAPHIC LOCATION

DESCRIPTION OF THE AREA

ENERGY LEVEL AREA

ASSUMPTIONS TO CHOOSE WELL

ARTIFICIAL LIFT RANKING

BASIC CONCEPT AGLS (ADVANTAGES)

LOCATION AND MECHANICAL STATE WELL

PETROPHISICAL

SPACING VALVE TO GAS LIFT

WELL STATE FINAL RESULTS

NODAL ANALISYS AND GAS PERFORMANCE

BEHAVIOR OF PRODUCTION

CONTRAST OIL GAS LIFT vs NATURAL FLOW

COSTS TO CONVERSION INDICATORS

CONCLUSIONS

CONTENT

Slide 3


GEOGRAPHIC LOCATION ORIGINAL PRODUCTION FACILITY:

EXPANSION ROCK AND FLUID AND CAPA OF GAS

P starting 11500 LPC

P Average 6168 LPC

Temp. Reservoir 280,4 °F 308 °F

Datum 14040 Pies

Porosity 10-15 %

Permeability 10-800 mD

API 26 - 32°

Slide 4


Fluid characterization according the

composition with depth Saturation pressure with depth

DESCRIPTION OF THE AREA

In this area is lost

between 50 to 80%

of the energy well

Pre

ssure

(psi)

Pressure Monitoring 2011

6461 psi

Slide 5


ENERGY LEVEL AREA

Slide 6


Wells of black oil reservoir

Wells with low pressure bubble

Wells with low to moderate GOR

Preferably wells w and s% <40%,

for the start of the project.

Wells with low energy level

(Pcab <600 psi)

Well not connected

Well low input history cleaning

Preferably wells must be located

nearby to facilitate surface facilities

(1st phase).

ASSUMPTIONS

ASSUMPTIONS TO CHOOSE WELL

BOSTON GRAPHIC

Opportunity Wells

Slide 7


ARTIFICIAL LIFT RANKING

Slide 8


Artificial Gas Lift Systems

The purpose of changing the gas-liquid ratio

in the fluid column by injecting compressed

gas. The gas reduces the weight of the

column so that the energy of the reservoir

will be sufficient to raise the yield to the

surface. It is necessary to inject the gas

deepest possible to substantially reduce the

weight of the column and inject the

appropriate rate of gas to the friction of

multiphase current does not annul the

weight reduction.

BASIC CONCEPT AGLS

Slide 9


Advantages

Flexibility to produce highest rates.

Nitrogen induction eliminate the possible interventionsin coiled tubing.

Efficient gas wells moderate relationship - liquid andsand production.

The computer underground is simple and inexpensive.

Maneuvers can be performed routine cleaning andstimulation without the need of rig.

No rig required intervention to enter the coiled tubing inthe well (3 days).

Disadvantages

The gas injection should be treated High initialinvestment in infrastructure .

ADVANTAGES AND DISADVANTAGES AGLS

Slide 10


N

Contornos estructurales cada 100’

Falla Normal

Falla Inversa

LEYENDA

Mechanical state before GLS

The well is completed with tubing 3 ½" to 15180'and them 4 ½" to surface, insulating between paker

the intervals: 15470'-480', 15530'-550' and 15570'-

600' NAR-3, and currently produces NAR-05.

LOCATION AND MECHANICAL STATE WELL

Slide 11


PETROPHISICAL

Intervals producers:

NAR-5: 15864’-15895’ (31’)

15902’-15925’ (23’)

15933’-15953’ (20’)

Pressure Monitoring 2011

Slide 12


SPACING VALVE TO GAS LIFT

Slide 13


WELL STATE FINAL RESULTS

Save time of completion as coiled tubing down takes an approximate 3 days while drilling operation with take about 90 days

Slide 14


Gas lift performance580 STB/D

CRC-19

P: 6000 psi

Ko Ave. 12 Md

TReservoir. 304 °F

H: 70 feet

API: 25.9 °Red. ¼”

GOR Aver. 550 Scf/Stb

S: 11

IP: 0.35 Stb/D/psi

Pb. 2740 psi

Nodal Analisys

1600 STB/D

NATURAL FLOW GAS LIFT

WELL STATIONRED

(INCHES)

Oil rate

(STB/D)

Gas Rate

(MMSCF/D)

Oil rate

(STB/D)

Gas Lift

Rate

(MMSCF/D)

Gas Rate

(MMSCF/D)

CRC-19 MUSIPAN 1/4 580 0.13 1600 2.27 0.882

NODAL ANALISYS AND GAS PERFORMANCE

Slide 15


BEHAVIOR OF PRODUCTIONS

TB

/D

Slide 16


BEHAVIOR OF PRODUCTION

Cond. DateQt

(STB/D)

Qo

(STB/D)%W AND S

GOR

(SCF/STB)

Qg

(MSCF/D )°API

REDUCE

R (in)

Php

(psi)

Plin

(psi)

Pinj

(psi)

Qig

(SCF/D)

A 12/01/2011 584,0 581,0 0,5 360 209 25,5 5/16 500 120 0 0

A 03/04/2011 740,0 739,0 0,2 275 203 25,3 5/16 500 110 0 0

A 07/01/2012 456,0 456,0 0,0 395 180 24,2 5/16 450 110 0 0

A 26/02/2012 552,0 552,0 0,0 654 361 24,2 5/16 350 130 0 0

A 12/03/2012 512,0 512,0 0,0 965 494 25,6 5/16 380 100 0 0

A 09/06/2012 364,0 364,0 0,1 1418 516 25,2 1/4 380 100 0 0

A 11/06/2012 372,0 372,0 0,1 978 364 25,2 1/4 380 100 0 0

A 12/07/2012 354,0 354,0 0,0 1158 410 25,5 1/4 380 100 0 0

A 07/08/2012 366,0 366,0 0,0 730 267 25,5 1/4 380 100 0 0

A 26/09/2012 336,0 336,0 0,0 640 215 24,9 1/4 380 100 0 0

A 20/10/2012 342,0 342,0 0,0 763 261 24,9 1/4 380 100 0 0

A 08/12/2012 318,0 315,0 0,8 994 313 25,1 1/4 380 100 0 0

A 13/01/2013 342,0 342,0 0,0 655 224 25,1 1/4 380 100 0 0

A 13/03/2013 276,0 276,0 0,1 797 220 25,1 1/4 380 100 0 0

A 28/05/2013 581,0 580,0 0,1 224 130 25,1 1/4 380 100 0 0

B 10/08/2013 1600,0 1600,0 0,0 453 3395 25,4 0 450 100 1800 2,92

B 13/08/2013 1422,0 1422,0 0,0 437 3291 25,4 0 450 100 1790 2,85

A 13/08/2013 1320,0 1320,0 0,0 398 3195 25,4 0 450 100 1760 2,79

B 15/08/2013 1582,0 1582,0 0,0 442 3370 25,4 0 440 100 1760 2,92

A 22/09/2013 1362,0 1361,0 0,1 328 2296 23,9 0 440 100 1730 1,97

A 09/10/2013 1380,0 1379,0 0,1 617 1951 23,9 0 430 100 1720 1,38

A 15/10/2013 1494,0 1493,0 0,1 67 1800 23,9 0 430 100 1730 1,73

A 27/10/2013 1582,0 1582,0 0,0 442 3370 25,4 0 430 100 1750 2,93

A 03/11/2013 1578,0 1577,0 0,0 442 3370 25,4 0 430 100 1750 2,93

A 18/11/2013 1320,0 1318,0 0,0 598 2390 24,4 0 420 100 1710 1,79

Slide 17


• Application of Gas Lift would increase the current production rate from 580-1500 BNPD

(+920 MBND).

• For an evaluation period of 10 years, the application of Gas Lift would increase the

accumulated approximately 2.08 MMstb, for a total of 4.88 MMstb oil.

CONTRAST OIL GAS LIFT vs NATURAL FLOW

Slide 18


COSTS TO CONVERSION INDICATORS

Associated Costs: 6.3 MM BLSF. (Buy Coiled tubing 1.5 "x12000 Feet) +

MMBSF 25.8 (laying of gas lift line is 2 "ID, 1.32 Kmts)

Total well costs X 32.1 MM BlsF. (The first one).

Gain estimated with LAG. 920 BNPD.

(Estimated time deferred production 3 days per

insert pipe into the well).

ECONOMIC INDICATORS

NPV: 25510

IRT; 1323 %

EI: 88.38 $/$

DTP: 207 DIAS

EXCHANGE RATE: 6.30 Bsf/$

COST OF CRUDE OIL: 96.72 $/BARRIL

Slide 19


• Artificial Lift System that applies to more wells area of Punta de Mata is gas

lift, followed by electrosumergible pump.

• The costs associated with the intervention LAG hole with coiled tubing is 32.1

MMBs. for CRC-19 well, and dynamic time of payment is 207 days.

• With the implementation of LAG in the CRC-19 well a flow rate of 920

additional BNPD be gained.

• In an evaluation period of 10 years, the application of Gas Lift with Coiled

tubing would increase the accumulated oil in approximately 2.1 MMSTB.

• With the implementation of this methodology, avoiding 90 days deferred

production, with an approximate saving of 22 MMBs.

• The critical path for this project put into operation is the construction of

surface facilities.

CONCLUSIONS

Thank You / Questions

Slide 20

SPE 169456 Assessment System First Gas Artificial Lift by ...

Documents