20748-Implementation of a Reservoir Management Program

7/24/2019 20748-Implementation of a Reservoir Management Program

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SPE 20748

Implementation of a Reservoir Management Program

G.C, Thakur, Chevron U.S.A. Inc.

3PE Member

Co py ri ght 1SS0, So ci et y c : et ro leu m Eng ineer s In c.

Th18 paper was p rep ar ~ : -.: : sen tal io n at t he 65t h A nn ual :ec hn lc al Co nf er en ce an d Ex hl bl li on o f t he s oc iet y o f Pet ro leu m En gi neer s h el d i n N ew Or lean s, A, Sap Iem bw 23-2

Th is p ep ar wae eel eo led f or p res en tat ion by an SPE Pr og ram Commi tt ee f ol lo wi ng r av ln w of i nf or mat ion c on tai ned In ar t abs tre~t su bmi tt ed b y Ih e au th or(s ). Co nten la o f I

aa p raaent ed , hav e no t b een r ev iewed b y t he s oc iet y o f Pet ro leu m En gi neer s an d are c wb jac l t o c or rec ti on b y th e au th or(a). The mat en ll , aa p res ent d, d oas no t r wes sar il

an y p +el ti on o f t he So oi e v o f Pet ro leu m En gi neer s, It a o f tl cer s, o r m em b r s. Pap er s p reeen ted at SPE m eet in gs ar e eu bj ac t t o p ub li cat io n r ev iew b y Ed it or ial Co mm it tees o f t h

o f Pe troleu m En ginw ra , Pe rm ission 1 0 co py Ie reat rk te d to a n a bs trac t o f n ot rnw e tha n S0 0 w orde . I ll us tral km e m ay m otb e cc +sd. l le a bs trac t ah ou kf o om aln ccm ap rcuo us ao kr ro W

o f wher e an d b y wh om t ha p apar i e p reeen ted , Wr it e Pu bl icat ion s Man ag er, SPE, P,O. Box 8336S8, Ri ch ard son , TX 7W6S4626.

Telex, 7S0969 SPEDAL.

ABSTRACT

Reservoir management can be defined as the

judicious use of various means available to maximize

benefits or economic recovery from a reservoir.

Although there are numerous reasons why reservoir

management programs sometimes do not succeed,

perhaps the most i,flportant reason is the lack of

team effort in developing and implementing such

programs.

A step-by-step procedure to improve

success in this effort is outlined.

Two distinct approaches have been utilized: one is

a comprehensive approach for large reservoirs and

the other is a problem solving approach for small

(and/or less profitable) reservoirs. Although the

approaches are philosophically qu te different, each

has produced useful results. It is not necessary

for all reservoirs to have the most comprehensive

management program; rather, it should be dictated

based upon need, keeping. the cost-benefit anal ysis

In mind.

INTRODUCTION

Reservoir Management has

received

sl~nificant

interest wlthln the petroleum Industry In recent

years. Although reservoir management ha? been in

practice in various forms since th~ 1930s , it has

gone through evolutionary stages,

Before 1970,

reservoir engineering and reservoir management

were considered synonymous by many. However,

during the 1970s and 19S0s, considerable changes in

this philosophy were Instigated, and the value of

synergism between

n~~terinj~te ~~~g~ltho~~~

geophysics was realized,

these alterations

were beneficial,

raservoi r

management still dld ,mt fully value the merits of

other disclpllnes, e.g. production

operations,

drllllng, and non-petroleum engineering functions,

References and Ill ustratlons at end of paper,

Recently the management of resewoirs has b

explained

as judicious use of various

me

available to maximize benefits fram a reservoir

Wiggins

and

Startzman

describe reservo

management as

~lthat set of operations and decisio

by which a reservoir is identified, measure

produced, developed, monitored, and evaluated f

Its

aband%~%;~z hrough epletion and f

Also, they explain it as

application

of state-of-the-art technology to

reservoir system

within a

given

managem

environment.

In summary, the function

reservoir

management

is to

provide

fac

information, and knowledge necessary to con

operations and obtain the maximum possible econo

recovery from d reservoir.

The purpose of this paper is to provide

overview of reservoir management, discuss

some reservoir management programs fail, and o

alternative methods to manage resmvoirs utilizi

two case studies.

WHY DO SOME RESERVOIR MANAGEMENT P

mml-?

There

are numerous reasons why

reserv

management programs have falle

1

Some are lis

below:

1

A) It was not considered as a part of a coup

system consisting of wells, surface facilitie

and the reservoir, Not all of these w

emphasized In a balanced way,

For examp

one could do well In studying the fluids

their interaction with rock, i.e. reserv

engineering; but, by not considering the

andlor the

surface system design,

recovery of oil and/or gas was not optimize

Most people can cite examples of mistakes m

in our business where we thoroughly stud

various aspects of the reservoir and m

decisions resulting in too many wells drille


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IMPLDIENTATIONOF A RESERVOIRMANAGEMENTPROGRAM

SPE

improper

application of

well

completion

c

Calhoun draws an anai~y between reser

technology, and/or inadequate surfac~- facilities

and health management ,

According to

available for future expansion.

concept, it is Rot sufficient for the reser

management teani to determine the state

Perhaps the most important reason why a

reservoirs heal.;~ and then attempt to imp

reservoir man(gement program

is deveioped

it. One reason for reservoir management

and implemented poorly is unintegrated group

ineffective is that the reservoir ar,d

effort.

Som@times the operating decisions are

attached systems (weils and surface facili

made by peclple who

do not recognize the

health (condition) is not maintained from

dependence of one system m the other. Also, siart.

the people

may

net have the required

background knowledge in critical areas, e.g.

reservoir engineering, geology and geophysics,

production

and drilling engineering, and

IMPROVING SUCCESS IN IMPLEMENTATION

surface facilities.

Although it may not be

..

absolutely

necessary

for

the

reservoir

management decision maker to have working

Table 1 describes a step-by-step procedure on

knowledge in all areas,. he/she must have an

to improve success in implementing a rese

intuitive feel for them.

management program.

Thakur recently emphasized the team approach

1.

The first step involves starting with a pl

to reservoir managel.)ent involving i~teraction

action, including all functions.

It is co

between various functions (Figure 1) .

It is

for many reservoir management efforts

suggested that the team members work as a

devise a plan, but this plan usually does

well-cnoroinated basketball team rather than

involve all functional groups.

Thus, no

a relay team.

Constant interaction between

groups buy into these programs, and

various functions is requ red in the team

cooperation between various functions is

effort.

Note that the synergism of the team

the desired Ieve

;f a plan is to be devel

approach Ran yieid a

llwhol~ is greater thai~

and implemented

ihe best way, it must

sum of its parts effect.

Thus, hlteract on

commitment from all disciplines,

inciu

between

various engineering functions,

management.

production operations, geolo~~thand geophysics,

and their

interaction

management,

2.

The plan must be flexible,

Even if

economics, proration, Iegai, and enviror~mental

reservoir management team members pre

groups

are both critical to a successful

pians by involving ali functional groups

resewoi r management program.

This statement

does not guarantee success if it is

is, basically an extension of the idea advocated

adaptable to surrounding circumstances (

by Talash that

I Teamwork hetvfeen reservoir

economic, legal, and environmental).

engineers and production loperations engineers

is essenti~l to

waterflood

project

3.

The plan must have managemeiv support.

management,

matter how good the plan is in (ethnical te

it must have local and h gher level manage

B) Reservoir management was not started eariy blessings. Without their support, it would

enough and when initiated, the management

have a chance to get approved,

Thus,

became necessary because of a crisis that

necessary that we get management invo

occurred and/or required a major problem to

from day one.

be fixed,

Early in,.iation of a coordinated

reservoir rrmagement

program couid have

4. No

reservoii management plan

can

provided a better monitoring and evaluation

implemented properly without the suppor

tool ,

and cost less in the long run.

FQP

the field personnel,

Time and time agai

example, a few eariy DSTS could have heiped

have seen reservoir management plans

decide if and where to set pipe.

Also,

because either they are imposed on

performing some tests eariy on could have

personnel without thorough explanations

indicated the size of the reservoir, If it were

they are ~,epared without their involvem

of limited size, driliing of unnecessary wells

Thus,

the fieid personnel do not ha

could have been prevented.

commitment to these plans.

Early definition and evaluation of the reservoir

5.

It is critical to have periodic review meet

system is a prerequisite to good reservoir

invoiving all team members. Most, if no

management. The collection and anaiysis of of these meetings should be held ht the

data play an important role in the evacuation of

offices. The success of these meetings

the system.

Most often,

an integrated

depend upon the ability of each team m

approach of data collection is not followed,

to teach his/her functional objectives.

especially immediately after the discovery of a

reservoir.

Also, in this endeavor, not all

functions are generatiy involved.

Sometimes

ALTERN,+TIVE WAYS TO MANAGE A RESERVOi

the reservoir management staff has difficulties

in justifying the data collection effort to the

management because of not clearly showing the

As discussed above,

a comprehensive plan

need of the data, along with its costs and

reservoir management, including a team appro

benefits.

is Lighly desirable, However, every reservoir

.


3/14

n~t warrant

such a detailed plan

b~cau~e of

cost-b~nefit considerations.

Keepi.]g this in mind,

two approaches utilizing case studies are described

in this paper.

The first case study,

North Ward Estes Field,

illustrates

the application

of a

comprehensive

approach,

whereas the second, Columbus Gray

Lease, discusses a IIproblem solvii~gll approach to

Weservoir management. Both approaches have

shown positive results, and, although they are

philosophically quite different, each has its own

merits.

The comprehensive approach philosophy is described

in detail in Ref. 2.

The fc iowing describes the

latter, i.e. the problem solving apl iroach:

o

An isction

pian

for

evaluating and

increasing the net worth of reservoirs is

prepared by involving a selected group of

personnel, and is based upon the best

available data.

o

in the problem solving sessions, an

informal exchange of ideas takes place

and probiems associated with current

operating practices are defined.

Next,

specific

recommendations

aimed at

enhancing

reservoir performance

are

suggested, and pros and cons for each

recommendation are evaluated.

If the

required reievant data are not available,

then either they are assumed or collected

in the field,

keeping the cost-benefit

analysis in mind.

NORTH WARD ESTES FiELD

Introduction

The North Ward Estes ( NWE) field, located in Ward

and Winkler Counties, Texas (Figure 2), was

discovered in 1929.

It is an lb mile x 4 miie

anticlinoriumo

Cumulative oil production from

primary and secondary recovery has been in excess

of 320 million barrels,

or about 25% OOi P, from

more than 3,000 wells.

The field has been

waterflooded since 1955.

Geologically, the fieid

resides on the western edge of the Central Basin

Piatform.

The field is part of an Upper

Cuadalupian

productive

trend

which extends

uninterrupted for 30 miles on the e:@ of the

platform (Figure 3).

The average reservoir depth is 2,600 feet; porosity

and

permeability

19% and 19 md,

respectively.

The t&~~$o;r temperature is 83F,

The flood patterns are generally 20-acre, five spots

and line drives.

Field informatlon and Geology

The fleid was Initially developed on 20-acre

spacing.

Later,

however, the most productive

parts of the field were drilled on 10-acre spacing.

Until the 1950s, the wells were mostly completed

open-hole and shot with nitroglycerine.

Perforated

liners were then hung from the casing, which was

E20748

G. C. lhakur

.

set above the productive formation

in the gas

sands.

After 1950, the welis were completed cased-hoie,

hydraulically fractured and acid stimulated. About

half of the current producers and injectors are

cased-hole.

Table 2 provides additional information

on the field histwy, structure, and s?ratigrapliy,

The producing formations are Yates and Quzen

sands, but most of the production has been from

the Yates sands (Figure 3).

They consist of very

fine-grained sandstones to siltstones, separated by

dense dolomite beds.

These sands, as shown in

Figure 4, are: A, BC, D, E, F, stray sands, Jl,

2

and J3.

Most of the BC was in the original gas cap and

consists of silt:,tones to finegrained sandstone with

clay. The D and E sands are similar to BC, The

stray is composed of thin bedded,

Ienticular,

siitstones and fine-g rained sandstones, with hiqh

clays. The J, and J

~> ~ds are compo~ed of

coarser sands

wi~avrluc:ghw clay content;

therefore, they

porosities

and

permeabilities.

Generally, the J3 is not well

developed and is wet in most areas.

The Queen formation, which lies below the Yates

sands,

is composed of intervals of fine-grained

sandstones to siltstones, composed of numerous

thin, ienticular sands with poor lateral continuity.

Thus, the Queen sand has been difficult to

waterflood.

Reservoir Management Team

A team including all functional groups, a. shown in

Figure 1, was formed to investigate ali .>ertinent

options for optimizing recovery from the field. The

results of the team effort are described below.

1. Geoiocalcal Characterization

A correlation scheme was developed for the field

based upon Iateraily continuous key dolomites that

bracket the productive sands and segment the

reservoir into discrete mappable units.

A computer

database was built by our geologists to facilitate the

processing and integration of large volumes of data

to aid in the geological characterization study. The

database components were:

A. Wireline log data from 3,300 welis, which

included about 15 million curve feet,

B,

Core data from 538 wells, which totaled about

30,000

feet of

analyses

and

Ilthology

description,

c.

Marker data for more than 60,000 correlation

markers.

D.

Fluid contact data, I.e. original gas-oil anu

oil-water.

E,

Production data,

consisting of historical and

wellbore data, Includlng diagrams.

Core analyses were depth corrected.

Logs were

normalized using a 60-foot interval cf laterally


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IMPLEMENTATIONGF A RESERVOIRMAWGFWNT PRoCRAM

SPE

continuous anhydritic dolomite. Core porosity data

were cross-plotted versus bulk density log value~

to develop transforms for derivation of porosity.

Corrections for hole rugoslty, overburden pressure,

and Iithologic complicat~ns were applied to refine

the porosity transform.

Jht? final transforms are

shown in Figure 5.

As seen in this figure, the correlation between

pxmosity and permeability is poor, However, when

the correlation based upon Ilthofacies was mad~o

increased correlation coefficients were obtained.

Structure and porosity-feet maps were merged with

fluid contact and water saturation data to calculate

volumetric.

Facies relationships and actual to

apparent p~y ratios were applied to determine

effective hydrocarbon pore volume, Computar

generated net isopach maps of the sands display a

north-south strike,

The sands pinch out into an

evaporite facies

updip and a

carbonate facies

downdip.

Reference 10 describes the details of the study.

About 11 man years and $1.6 million were spent to

ach~we the above resu Its,

Figure 6 summarizes

computer-aided characte, ization study

steps.

Normalized log and cme data, markers, fluid

contacts, and production data were quality checked

and corrected for any errors.

The output Included

maps (structure, Isopach and porosity-thickness),

porosity vs.

permeability plots, water saturation

and

volumetric data,

production

plots,

and

cross-sections,

including wellbore diagrams. An

example of a sand trend cross-section is shown in

Figure 7.

It is based upon basic geologic data and

supported by production data.

One of the outcomes of the characterization study

has been identi flcation of well workovers. I n

addition, several waterflood projects were designed

and implemented. A waterflood project that did not

prove as successful as others was later analyzed in

terms of the characterization study.

If the project

had been considered after the study, it probably

would not have been implemented and considerable

savings could have been attained,

2. C02 Injectivity Test

A CC injectivity test was conducted to investigate

any ,i,jectivity reductions during C02 and water

Injection cycles.

An injector in good mechanical

condition and with no hydraulic fracturing was

selected.

Geological cross-sections through this

well showed weil-developed sands,

The injectivity

test provided valuable information, as described

below:

(A) No reduction In injection rates was observed

during or after C02 injection,

(B) The C02 Injection rate was about 20% higher

than the water Injection rate.

(C) NO significant change in injection profile was

observed during or after COa Injection,

In addition to the above-mentioned results, the C02

injectivity test implantec a valuable IIseedll of team

effort that led to fruitful results during the design

and Implementation of the COZ project,

3. COZ Proj >ct Design and Implementation

The C02 flood design was based upon a his

match

of

the

waterflood performance of

six-section pr~ject area, the sel~tion &

typ

patterns

~flcluding a

detailed

reser

characterization, a prediction for continuation o

waterflood, predictions for C02 flooding . and

scale up of t~f pattern predictions to the e

project area,

Predicti Ins were made

continuation of the waterflood tmi for C02 flood

Additional reservoir simulation was conducted

determine the optimum C02 slug size.

The ant icipated increase in oi I recovery from

six-section, Stage 1 area (containing 165 produc

wells and 192 injection wells) as a result of

flooding is 16.5 million bbl of oil. Stages

2

an

tentatively scheduled for 1993 and 1995, will dep

upon the success of the first stage and on

price.

Management approval of this project was obtained

December 1987,

In January 1988, i) task force

formed,

and the C02

kIl:CdOf7 was

initiated

March 1989.

Currently, about 60 ,$fMCF/D of

and hydrocarbon gas is being injected. To d

project response has been encouraging.

The Cat plant compresses, desulfurizes,

dehydrates all C02-rich gas produced from

project.

The plant is designed to process

MMCF/D of produced gas. In addition to reinfec

gas, the plant will also produce four (4) tons

day of marketable

sulfur

from mode

concentrations of H2S (2%) in the hydrocarbon

Team Effort

1. Why a Team Effort?

The North Ward Estes Field is one of Chev

U .S. A,S largest fields, and it has significant

potential. C02 f ooding was the only econ

option available to recover significant reserves

this field.

For about 1,3oO producing wells.

average production rate is only 7 130PD at

water cut.

Out of the 1,300 wells, about 700

5 BOPD or less,

Also, 300 wells are now capable

producing only at or below the present econ

limit. Thus, if C02 flooding was not implemen

right away, economics would have dictated plugg

and abandoning of uneconomic wells.

Keeping the above points m mind and consider

the average age of wells In the field of about

years, a

window of opportunity became q

obvious. If the wells were abandoned, It

unlikely that the

project would have

undertaken because economics would not

justified re-drills, Thus, it became urgent to s

an EOR project, i.e. either move quickly or

losing the chance,

To design and implement

EOR project and to Improve the performance of

existing waterflood,

a study team, as shown

Figure 1, was formed,

2. What Did the Team Achieve?

During the dee:gn phase , as many as 25 to

members

of various f~nct: n]al groups wor

We


5/14

.

.

E 20748

G. C. Thakur

C.yether on a comprehensive design of a six-section

Coa

The Iaterai variability of porcsity development

project,

reviewed hundreds of workover

candidates,

and

makes weii to weii correlations difficuit,

evaluated

severai

waterflood

modification projects.

The average depth to the top of the USA is 4,25

feet.

The average porosity, permeahiiity, nt~t pay

COZ injection was started in the six-section area

and water saturation are 9.3%, 2.6 md, 80 ft. an

within 15 months of project initiation.

In addition,

35%, respectively.

Aithough no discrete o,l-wat~r

many workovers and waterflood modification projects

were

contact (OWC) is present within this interval, som

implemented during

this

time period.

water is produced.

Moreover, within a year-and-a-haif, the gas

processing piant was buiit and started. The teams

The Lower San Andres ( LSA) is about 60 fee

goai for every aspect of the project, from weii

thick,

and comprises the lowest part of th

workovers,

reservoir studies, CCl injc


6/14

.

....

+-.&l,,Arh* L,,

n

Au. *,,, &m uw

tlnmu,,~

rnvvmx

ar

example is Well 2126, once producing 5

management

program is

developed

BOPD,

is now averaging 17

BOPD after

implemented poorly is unintegrated

workover

(cleaning

out ,

adding

effort.

A procedure to improve succe

perforations, and acidizing) .

implementing such as

program has

employed.

3.

Although, by recompleting in the LSA,

some response has already been obs~ rved,

3.

Both the comprehel~sive approach and pr

it is believed that additional production

solving approach to reservoir management

increase will be seen in the southern

resulted in positive results, and although

portion of Section 21. The wells in this

are philosophically quite different, eac

area were only completed in the USA and,

shown its merits.

as ~lescribed above, this interval has a

rr,uch lower porosity and permeability.

4. The North Ward Estes field illustrates

application of

comprehensive

res

4. Since the parting pressure in Section 19

management, whereas the Columbus Gray

incr?ased, the injection pressure and rate

depicts a

problem

solving approach

were also raised.

reservoir management.

5.

The producing water-cut is too high for

the relatively low volume of water injected

ACKNOWLEDGEMENTS

(about 10% and 60% HCPV in the USA and

LSA, respectively).

This high water-cut

The author expresses his appreciation to

indicates: (i) channeling from the

management of Chevron U.S.A. Inc. for perm

injectors to producers through fractures

to publish this paper.

The content of the pa

and/or high permeability zones, and (ii)

primarily

derived

from

in-house

Res

poor volumetric sweep in the LSA.

Management forums and workshops coordinated

the author. The work performed by

6. Several recommendations

involving

participants of these forums {from geology

pumping down the high fluid level wells,

geophysics, all engineering functions, drilling,

increasing injecton pressure due to the

production operations) is highly appreciated,

increased frac pressure, running profiles

before and after the increase in pressure,

and

diverting

injection to

match

REFERENCES

production profile.

7.

Several

of the above

recommendations

1.

Stiles, L. H,:

llReservoir ManagemelTt

have already been incorporated.

These

Means San Andres Unit, SPE Paper

cGst about $750,000, and will result in an

20751, presented

at the Arlnual Tech

estimated total ploduction

increase of Conference, Sept. 23-26, 1990, New Orl

250,000 130.

LA

This discussion Illustrates

that identifying and

2.

Thakur, G. C.:

Reservoir Management:

methodically solving

reservoir

problems

has

Synergistic Approach, SPE Paper No.

increased the performance of the Columbus Gray

presented at the Permian Basin Oil and

lease.

Conference, March 8-9, 1990, Midland,

3,

Craig, ~, F, et al:

lOptimized Rec

Reservoir Management

Through

?ontinuing

Interdisciplin

Cooperation(, J, Pet, Tech.

(July

The reservoir management approach followed was

pp. 755-760

very simple in this case because the lease

production rate was only about 300 130PD at the

4.

Harris, D. G, and Hewitt, C, H,: ISyne

time

of the study,

Based upon reservoir

in Reservoir Management -- The Ge

heterogeneity and past performance, the expected

Perspective, J, Pet, Tech, (Juiy 1977),

increase In production was not considered high.

761-770

~hus, a declslon \Vas made to design and implement

a cost-effective reservoir management program that

5.

Calhoun, J. C,:

11A Definition of Petr

the lease could support.

Depending upon the

Engineering,

J. Pet. Tech, (July 1963)

success

of the implemented program, additional work

may be recommended, 6, Talash, A, W,: llAn overview of Wate

Surveillance and Monltoringtl, J. Pet,

(December 1988) , pp. 1539-151+3

CONCLUSIONS

7,

Weber, K. J.:

influence

of Co

1,

Reservoir management has been described as

Sedimentary Structures on Fluid Fio

the judicious use of various means available to

Reservoir Modelslt, J, Pet. Tech, (

maximize benefits from a reservoir,

1982) , pp. 665-672

2,

There are numerous

reasons

why

some

8, ;{avlena, D,:

Iinterpretation, Averaging

reservoir management programs fail.

Perhaps Use of the Basic Geololglcal -

Engineering

the most Important reason why a reservoir

Datail, J. Canadian Pet. Tech., Part 1,

w


7/14

.

.

2?

7Jl1711R nl- fl%., L..

---, ,.,

v A,, amu

No.

4 ( october

- December 1966), PP.

153-16~; Part 2, V. 7, No. 3 (July -

September 1968) , pp. 128-144

9.

Harris, D. G.:

The Role of Geology in

Reservoir Simulation Studiesll, J, Pet. Tech.

(May 1975), pp. 625-632

10.

Stanlev,

R. G. et al:

I North Ward Est~s

Geological Characterization , to be published in

1990 AAPG 13u letin

11.

Winzinger, R. , et al:

llDe~ign

Of a Major

c02

Flood -

North Ward Estes Field, Ward County,

Texas, SPE Paper No. 19654, presented at

the SPE Annual Technical Conference, October

8-11, 1989, San Antonio, Texas

12.

Wiggins,

M. L. and Startzman, R. A. An

Approach

to Reswwair Management,

SPE

Paper No. 20747,

presented at the Annual

Technical Conference, Sept. 23-26, 1990, New

Orleans,

LA

341


8/14

sp~ 74Q

TABLE 1

HOW TO IMPROVE SUCCESS IN IMPLEMENTING A

RESERVOIR MANAGEMENT PFiOQRAM

START WITH A PLAN OF ACTION,

INVOLVING ALL FUNCTIONS

FLEXIBLE PLAN

MAN:,QEMENT SUPPORT

COMMITMENT OF FIELD PERSONNEL

o PER1ODIC REVIEW MEETINQS, INVOLVING ALL

TEAM MEMBERS (INTERDISCIPLINARY

COOPERATION IN TEACHING EACH OTHERS

FUNCTIONAL OBJECTIVES)

TABLE8

North Wud Eaba Fkld

tusIQBx

19E9-NORTHWRD FIELDDISCOVERED

~W. OBRIEN 4 8E~10N W

i@W-BOTEO FIELD DIBOOVERED

EsW.E8TE0 l BEOTION BB

t044+lELDB COMBINED

GlB8&MTER FLOOD DEMN

WE* FOLYMER PROJUOT8 BEQAN

$ 00

WELL~ DRILLED

MTIVE WELL6-1 01 PRODUCERa 0@2INJEOTOR8

(0/1/07) W ME BPAOIN9

LOW RELIEF ANTIFORM

OENTRAL DAWN

PLATFORMHOMOOLINE

PRIMARY PRODUCTIONUVX7E0

wEnME DEPTH4B90

SECONDARY PRODUCTION-OUEEN

mmm DEPT+BW

. m+mmu am

mwwuw)

LITH--VERY FINS ORAIN EAHD AND 81LT-

BTONEB DOUMWE ANtlYDRITE INTRRBEDDSD

ERMR POROBITY+SS

*

MRAW pmnmmkv-ti d

SNVIRONMENT=TIML FLAT

342


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Documents

20748-Implementation of a Reservoir Management Program