mod 9d - full-field simulation, elk hills, ca

8/13/2019 Mod 9D - Full-Field Simulation, Elk Hills, CA

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NExT all rights reserved

Module 9D

SPE 68879

Fullfield Numerical Simulation Using Geostatistical Reservoir Model of Upper Main Body

B Reservoir, Monterey Stevens Formation, Elk Hills, California

By:

Tom Hampton, Schlumberger, H-RT

Corinne Danielli, Oxy Elk Hills

Don McChesney, Oxy Elk Hills

S.P. Singh, Oxy Elk Hills

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Study Objective

Evaluate infill drilling, re-completion of wells

Evaluate pattern waterflooding in selected areas

Forecast production and injection volumes for facilities sizing

and design.

Identify additional artificial lift requirements

Validate OOIP, IGIP, and remaining free gas


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Workflow and Project Schedule

Workflow and Project Schedule were created for the integrated

project team

Keys:

tight time schedule

cost efficiency

See next 2 slides

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Integrated Study Workflow

Static Model -> Dynamic Model

PredictionsWellbore

HydraulicsVFPi

Grid buildingFloViz, GRID

Well datapreparationSchedule

Rock dataSCAL

Geological model

Processing

Eclipse

100

Analysis

GRIDFloViz

Graf

History Matching

Events,

Production data


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TASKTASKDefine project goals, objectives and scope

DATA COLLECTION AND QC

Add core, log, pressure, production, injection, completion data

PETROPHYSICS

Review, Rebuild, Re-apply Petrophysical Model

GEOLOGY

Review Markers, Develop Stratigraphic Model, Make 3D Model

GEOSTATISTICAL MODELING

Load (RC)2, Run Variances, Review 3D Model, OOIP, IGIP

SIMULATION FLOW MODEL CONSTRUCTION

Define Simulation Grid, Upscale, Import to Eclipse, Initialize

FLOW MODEL HISTORY MATCHING

Prepare Rate Schedule, Match Pressures, Sat. PI's, Sensitivity

FLOW PREDICTIONS

Base Case, Prediction Cases, Document

PHASE II UPDATE WITH SEISMIC

Qtr 2 Qtr 3 Qtr 4 Qtr 1 Qtr 2 Qtr 3 Qtr 4 Qtr 1 Qtr 2

1 2 3

Repeat Process

with Seismic

Interpretation

Simplified Workflow

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Material Balance MatchBefore History Matching - 1

Material balance model developed with same properties

as FFM

Recorded gas and water injection rates resulted in a field

pressure several thousand Psi too high


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Assumed that fluids migrated into the Shale Reservoir

injection wells fractured

Injection water lost 20%

Injection gas lost 50%

These results used in FFM.

Material Balance Match

Before History Matching - 2

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Reservoir Characterization

Geological mapping and correlation

Nine zones sand beds laterally extensive- provide lateral

flow continuity

Logs from 725 wells 413 modern log suites

28 wells cored


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Geostatistical Model

Sectors

PHIE

PERM

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Numerical Simulation Model

240 x 240 x 20 feet grid blocks

20 layers

82,000 active cells

Geostatistical software upscales/scales-up from 25,000,000

cells to 82,000 grid blocks

Only one realization used for HM


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20 LAYERS,

82,000 active cells

260 LAYERS

~25,000,000 cells

Upscaling & Volumetrics

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Oil In Place by Layer and Sector

R E P O R T O U T B Y L A Y E R

Layer

U B A

U B A 1

U B A 2

U B A 3

U B B 1

U B B 2

U B B 3U

U B B 3L

U B B 4

L

A

Y

E

R

S

OO IP, M M STB

E clips e

R E P O R T O U T B Y S E C T O R

N FTR

S E N O S

3G -4G C TL

5G -32S

C TL

31S C rest

N o rth

31S C rest

S outh

N W N O S

TO TAL

R

E

G

IO

N

O O IP , M M S T B


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Fluid in Place Regions

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Sequence of History Match

Pressure match

Field water oil ratio match

Field gas oil ratio match


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History Match of Field Rates and Pressures

WATER, BWPDPRESSURE

OIL, BOPD GAS, MCFPD

Red - Historical

Black - Simulation Model

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History Match GOR


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History Match WCUT

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Start

At End of

History Run

Oil Saturation from

Cross Section Using FloViz


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Key Changes Required In the HM Process

To match water production:

Reduce vertical permeability

To match gas production:

Add reservoir volume near large gas injector

Modify gas relative permeability

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4 Prediction Cases

Base case continued operation of current wells

Evaluate a project that is underway

Conversion of 24 producers into water injectors

Effectively converting from peripheral water flood to

pattern

Reduce water injection with no conversions


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6 8 68

68

68

67

67

66

66

65

6565

64

64

64

63

63

63

62

616

59

58

5756

5554

535251

5

49

48

3 23 3

3 4

34

5

322H -32S

326-32S

338-32S 348-32S

366-32S

378-32S

384-32S

388-32S

326-33S

344-33S

346-33S

348-33S

366-33S 386-33S

388-33S

326-34S

337-34S

344H -34S

346-34S

348-34S

366-34S

368-34S

378-34S

384-34S

386-34S

388-34S

316-35S

318-35S

324-35S

326-35S

328-35S

334-35S

336-35S

338-35S

344-35S

346-35S

348-35S

312-2G

3 22 -2 G 3 42 -2 G

314-3G

322H -3G

324-3G

342-3G

344-3G

354-3G

362-3G382-3G

322H -4G

324-4G

343-4G

362-4G

364-4G

382-4G

384-4G

321-5G

322H -5G

344-5G

352-5G 362-5G

384-5G

375-33S

373-4G

357-34S

351-4G

313H -4G

351H -5G 311-3G

373H -5G

333-5G

368-33S

317-34S

357-35S

315-33S

331-4G

373-3G

337-33S

331-3G

9-354H -4G

317-33S

371-4G

346-32S

313-5G

335-34S

377-33S

342A -3G

333-3G

351-2G

357-32S

357-33S

313-3G

311-4G

328-34S

375-34S355-32S

333-4G

382H -5G

324-32S

364H -32S

375-32S

386-32S

335-33S 355-33S315-34S

333-2G

353-3G

364-3G

315-4G

355-35S

353-5G

355-34S

313-35S

384-3G

331-2G

364-5G

333-34S

322-35S

335-4G

313-2G

353-2G

353H -35S

335-3G

313-34S

355-4G

324-34S

375-4G

311-2G

375-5G

337-35S

335-35S

5-377-34S

333-35S

324-33S

353-34S

373-34S

322-34S

384-33S

381-31S

333-33S

324-2G

368A -32S

373-33S

364H -33S

342-34S

382-33S

318-32S

365U -4G

315-3G

333A -34S344A -32S 314-33S

373-32S

333-32S

374-34S

335A -5G

382-32S

314X -5G

324X -5G

355X -5G

364-34S

332-32S

353-32S

385-34S

364X -33S

365-34S

353-33S

376-34S

345-34S

315A -34S

385X -33S325-34S

356-34S

362-32S

336X -34S

374-33S

343-34S

354-34S

362-34S

314-34S

363X -33S

323-34S

352-32S

371-3G

342-32S

331-32S

342X -35S

327-35S

332-5G

383-5G

321-2G

321H -3G

363-5G

347-35S

323-4G

351X -32S

315-35S 325-35S

317-35S

362A -3G

381-4G

387H -34S

342-4G382A -5G

327-34S 347-34S 367-34S

352X -3G

338-34S

311H -5G 341-5G

358-34S

361X -5G

324A -33S

367X -33S

387-33S

376-33S

378-33S

314-35S

328-32S

328-33S

385-32S

351X -4G

356X -33S

312-4G

344-32S

338-33S

316A -32S

318-34S

381-5G

347-33S

368X -32S

327-33S

337H A -33S

327H -33S

338H -33S

368A H -32S

315H -33S

367-33S

358X -33S

377H -32S327X -33S

358A -33S348X -33S

357A -33S

327H -32S

367-32S

372-4G

332-4G312X-4G 342X-4G

316X-34S

346X-34S

Case3: 24 conversions, 1 new well

381X-4G

Pattern WaterFlood

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Predictions: Oil Production Rates

1. Continued operation

2. In progress project

3. Convert 24 wells to water injection

4. Reduce water injection


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Prediction Cases: Recovery and Peak Rate Results

PREDICTION

CASES

PERCENTIMPROVEMENT

RECOVERYPeak Oil Rate

BOPD

1BASE CASE 0.0 6,800

2 CURRENTPROJECT 2.5 7,800

3 PATTERN 24CONVERSIONS 5.8 11,300

4 REDUCEDWATER

INJECTION-10.3 6,800

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Limitations of Model

Seismic Interpretation was not available for this model.

Does not have detailed faults.

Communication established in West UMBB.


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Value of Simulation Study

Improved Utilization of Existing Data

Improved Understanding of Reservoir

Communication with Other Reservoirs

Vertical Transmissibility Between Layers

Different Areal (Sectors) Reservoir Behavior

Model to Make What If Scenarios

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Conclusions:

Time savings

Geostatistics reduced history match adjustments

parallel processing

Integrated Team Approach

Geology, Geophysicist, Engineering provided improved model

understanding

Improved development planning of UMBB

mod 9d - full-field simulation, elk hills, ca

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