maximizing the value and recovery of oil and gas resources ccop-lemigas rev2.pdf · maximizing the...

Maximizing the Value and Recovery of Oil and Gas Resources

Research and Development for Oil and Gas Technology “LEMIGAS”Ministry of Energy and Mineral Resources

Republic of Indonesia

CCOP-DMF Project on Petroleum Resources/Reserves Classification and Reporting System (S5)

Bangkok - Thailand8 – 10 September 2015

CONTENT

1. INDONESIA RESERVES DEFINITION AND CLASSIFICATION

2. OBTAINING DATA FROM OIL/GAS COMPANIES

3. POD/POFD

4. POTENTIONALITY TO GAIN MORE ADDITIONALRESERVES

INDONESIA Reserve ClassificationReserves Classification that is used by Indonesian Government (SKK Migas and Oil and Gas General Directorate) refer to SPE 2001 and it have been modified based on the reservoir character in Indonesia.

Commercial

Reserves

Proved Estimate

ProbableEstimate

Developed Undeveloped

PossibleEstimate

90%P1 + 50%P2 Or 90% P1

Sub -Commercial

Annu

al R

eser

ves

Rep

ort

POD

Source: SKKMIGAS

Reserves Classification (More detailed)

Oil and Gas Reserves

Primary

Secondary

Proven

Probable

Possible

Developed

Not yet Developed

Active

Inactive

Production Phase Probability Level

Development Status

Productivity Level

Reserve classification that is more detail can be done by each formation

Source: SKKMIGAS

The Summary of Hydrocarbon that originally in the reservoir that can be produced by current available technology until certain times.

Cumulative Production

Reserve Left in Reservoir

Oil Potention in IOR/EOR Phase

Oil Reserves in Natural Recovery

Original OIL In Place (OOIP)

Reserves Definition

Source: SKKMIGAS

(”Proven Reserve”) :Summary of Hydrocarbon that is found in Reservoir Rock and proven to be produced by using current available technology with trust/acceptance level in about 90% based on well log, geological and reservoir engineering and it is backed up by actual production data or production flowing test.

Proven = P1 ≠ P90

Reserves Criteria Classification

Source: SKKMIGAS

(”Probable Reserve”) :Summary of Hydrocarbon that is found in Reservoir Rock and proven to be produced by using current available technology with trust/acceptance level in about 50% based on well log, geological and reservoir engineering and it is not yet backed up by actual production data or production flowing test.

Probable = P2, 2P = P1 + P2, 2P ≠ P50


Source: SKKMIGAS

(”Possible Reserve”) :

Summary of Hydrocarbon that is found in Reservoir Rock and proven to be produced by using current available technology with trust/acceptance level in about 10% based on the correlation of geological and geophysical data, Reservoir Engineering but without any well log.

Possible = P3, 3P = P1 + P2 + P3, 3P ≠ P10


Source: SKKMIGAS

• Boundary of P1 vertically (Proven) : Based on the level of Oil Water Contact (OWC) or Gas Water

Contact (GWC) where the determination of fluid level contact must be supported by production flowtest, petrophysics interpretation, and pressure gradient analysis.

If OWC or GWC can be certainly determined, then there is no boundary of P2 or P3 vertically in the same reservoir.

If Fluid Contact can not be determined, then the vertical boundary of P1 is the lower level of production test (DST).

If the resistivity profile below the production test (DST) interval shows the bigger value and also supported with good reservoir properties, then the vertical boundary of P1 is allowed to reach the Lowest Known Oil (LKO) or Lowest Known Gas (LKG).


Source: SKKMIGAS

• Boundary of P2 vertically (Probable) :

The boundary between P1 (lowest tested interval) till edge of (LKO/LKG).

If the boundary of P1 is at LKO/LKG (lowest tested = LKO/LKG), then the boundary of P2 is between P1 andhalf of vertical edge of spill point or Highest Known Water (HKW).

• Boundary of P3 vertically (Possible) :

The area boundary between P2 and Spill Point or Highest Known Water (HKW)


Source: SKKMIGAS

Classification of Reserve Category based on Well (Vertically)

GWC

Prod. TestGas Flowing

Proven

Illustration - 1Edge of P1 could be determined vertically based on fluid level (OWC/GWC), where it should be supported by production test (DST), Petrophysics Interpretation, and Pressure gradient.

Prod Test. Water Flowing.

Source: SKKMIGAS

RTGR

A

B

tes prod.

Proven

Probable

Illustration- 2

LKO

Probable

Classification of Reserve Category based on Well (Vertically)

Source: SKKMIGAS

• Lateral/Areal Boundary of P1 (Proven) 1.5 x of Radius Investigation from flowing production test (DST) at the

representated Zone 1.5 x of depletion radius that is counted by decline analysis of production

profile from well that have been produced. If there is no DST data available, then the approximation of the edge of

area P1 is 250 metres maximum for Oil reservoir with API > 300, and for gas Reservoir, the maximum area is 750 m.

• Lateral/Areal Boundary of 2P (Proven + Probable) 2.5 x Radius area P1 (Proven). If the area P1 is restricted by different facies or there is fault, then the

area in which there is no well available, is categorized as P2

• Outside the area 2P in the same structure, is categorized as Possible (P3).

Classification of Reserve Category based on Well (AREA)

Source: SKKMIGAS

OBTAINING DATA FROM OIL/GAS COMPANIES

• ANNUAL RESERVES REPORT WHICH CONTENT

WHAT OPERATOR SHOULD SUBMIT TO THE GOVERNMENT?

I. COVER LETTER- Brief Explanation- Revision of Reserves- Revision of Map- Reclasification of Reserves- New Discovery

II. CONTRACT AREA MAP- Oil Field Location- Gas Field Location- Undeveloped Field Location

III. RESERVES AND PRODUCTION SUMMARYA. Estimated Reserves By Field By Reservoir

B. Revision of Reserves

C. Production

Source: SKKMIGAS


I IV. APPENDICES / ATTACHMENTS1. Individual Reservoir Data - Form : D-2

GEOLOGICAL DATA ENGINEERING DATA PRODUCTION AND INJECTION DATA RESERVOIR RESERVES CALCULATIONS

Method of Calculation Type of Reservoir Drive

2. Top Structure Map 3. Net Isopach Map 4. Production Performance Figures5. Other Supporting Data : Estimated Economic Limit, Gas

Composition, Gas Utilization, Platform Location Map, Structure Cross Section, Type Well Log Section - Etc.

ANNUAL RESERVES REPORT CONTENT

Source: SKKMIGAS


Reporting Resources from oil/gas Companies (KKKS):

• 2013 – now : Reporting using Online Website

• Before 2013 : Manual reporting using MS Excel

Standar format reporting on Resources from each oil/gas companies (PSC) will make the analisis and calculation of resources more accurate.

1. Reporting Preparation2. Filling form “PLAY” 3. Filling form “ LEAD”4. Filling form “ DRILLABLE PROSPECT”5. Filling form “ POST DRILL PROSPECT”6. Filling form “ DISCOVERY POSPECT”7. Uploading Map, figures and diagram8. Printing out Report “PORTFOLIO ASSET”9. Sending hardcopy to SKK MIGAS

On-line websiteSKK Migas

Reporting resources online stages:

The reporting online website:

AVAILABILITY INFORMATION PLAY LEAD DRILLABLE POST DRILL DISCOVERY

NAME √ √ √ √ √

GEOGRAPHIC COORDINATE √ √ √ √ √

BASIN √ √ √ √ √

ROCK / FLUID PROPERTIES FROM ADJACTION √ √ √

WELL DATA √ √

GEOLOGY SURVEY √ √ √ √ √

GRAVITY SURVEY √ √ √ √ √

GEOCHEMISTRY SURVEY √ √ √ √ √

ELECTROMAGNETIC SURVEY √ √ √ √ √

RESISTIVITY SURVEY √ √ √ √ √

OTHERS SURVEY √ √ √ √ √

SEISMIC 3D SURVEY √ √ √

WELL TESTING √

WELL PETROPHYSIC √

ROCK PROPERTIES √

GAS DEVIATION FACTOR √

INITIAL FVF √

OIL VISCOSITY √

GCF DESCRIPTION √ √ √ √ √

GRA √ √ √ √ √

CLOSURE AREA √ √ √ √

VOLUMETRIC √ √ √

Data requirement for reporting:

PLAY AdministrationGeographical BlockBasinProvinceGeologicalBy Analog toDistance to Analog Exploration methodEnvironmentOnshore/offshoreTerrainAdjacent ActivityDistance Nearby FieldDistance Nearby InfrastructureGCFSource rockReservoir rockTrappingDynamic

LEAD AdministrationLink PlayStructure NamaLead NameClarified byLead Name Initiation DateCenter CoordinateEnvironmentOnshore/offshoreTerrainAdjacent ActivityDistance Nearby FieldDistance Nearby InfrastructureSurvey Data AvailabilityAcquisition YearTotal Crossing lineAverage Spacing Parallel Interval2D Closure Low, Best, and High Estimate

Mandatory data requirement for reporting:

DRILLABLE Prospect AdministrationLink PlayStructure NamaDrillable NameClarified byLead Name Initiation DateCenter CoordinateEnvironmentOnshore/offshoreTerrainAdjacent ActivityDistance Nearby FieldDistance Nearby InfrastructureAdjacent Well DataPorosity P90, P50, P10Water Saturation (Sw) P90, P50, P10Year AcquisitionGross ReservoirThicknessNet Pay Thickness P90, P50, P10Area Closure Estimation P90, P50, P10

POSTDRILL Prospect AdministrationLink PlayStructure NamaPostdrill NameClarified byLead Name Initiation DateCenter CoordinateEnvironmentOnshore/offshoreTerrainAdjacent ActivityDistance Nearby FieldDistance Nearby InfrastructureYear AcquisitionGross ReservoirThicknessNet Pay Thickness P90, P50, P10Area Closure Estimation P90, P50, P10Well DataWell NameCoordinateWell ResultWell TypeOnshore/OffshoreTerrainWell StatuesFormation TargetHydrocarbon IndicationOil Show ReadingGas Show ReadingBoi (Max – Mean – Min)Bgi (Max 0- Mean – Min)Well Data Clastic/non-clasticGross Res. Thickness, Res. Vshale, NTG, Porosity , Saturation (P90, P50, P10)GRT, Res. DTC., Res. Total Pore. Porosity, Saturation (P90, P50, P10)


DISCOVERY AdministrationLink PlayStructure NamaDiscovery NameClarified byLead Name Initiation DateCenter CoordinateEnvironmentOnshore/offshoreTerrainAdjacent ActivityDistance Nearby FieldDistance Nearby InfrastructureYear AcquisitionGross ReservoirThicknessNet Pay Thickness P90, P50, P10Area Closure Estimation P90, P50, P10

Well DataWell NameCoordinateWell ResultWell TypeOnshore/OffshoreTerrainWell StatuesFormation TargetNumber Penetrated Production ZoneZone NameWell TestWell RadiusHydrocarbon IndicationOil Show ReadingGas Show ReadingBoi (Max – Mean – Min)Bgi (Max 0- Mean – Min)Well Data Clastic/non-clasticGross Res. Thickness, Res. Vshale, NTG, Porosity , Saturation (P90, P50, P10)GRT, Res. DTC., Res. Total Pore. Porosity, Saturation (P90, P50, P10)


• Original reporting must be submitted before 31 Juli every year.

• Revised reporting must be submitted before end of year.

Type of Reporting and Schedule:

Country borderLand of Indonesia

Land of neighboring countriesBasin with oil production

Basin with hydrocarbon discovery

Basin with hydrocarbon indication

Basin no hydrocarbon discovery yet

Basin no exploration

Oil and gas working areas

Working Area Map of Indonesia

Symbol

259 Company Operators

Field and working area oil/gas Indonesia:

Report 2014

Field and working area oil/gas Indonesia:

Report 2014

Classification of POD (Plan of Development)

Plan of Development I

Plan of Development I is the first POD in a working area to get the Minister of Energy Approval, by recommendation of SKK Migas, after consulting the local Government.

Remarks: This POD marks the changing between a working area from exploration phase into Exploitation/Production Phase

Classification of POD


Plan of Development II

POD II (etc) is the next type of POD from the different reservoir structure at the same working area that has been approved before (POD I).

Remarks : This type of POD should/must get approval from the Head of SKK Migas.

POD SecRec/EOR is the development of field to produce oil with SecRec/EOR methods. Proposed POD is only contains the production that has same number with the production from that field minus baseline production that is agreed by SKK MIGAS and PSC Company.

Classification of POFD (Plan of Further Development)

•POFD is the next plan of development for a field that has been produced in the same reservoir structure , where all of the establishment of production facilities and drilling plan that has been approved on the previous POD is done.•For some fields that has been produced for a long time with no POD before, if there is a plan for next development, then the POFD is a must.


•Field P,Q,R,S is in Working area A•Field U and V is in Working area B•Field U and Field P have facility that can be used by Field S•Field W is in Working Area A and B, it needs utilization•POD I in Field P as First Field, in reservoir X and Y•POFD in field P includes Reservoir Z•POD II in field R as the second Field in Working Area A, After P•POP in Field S, using facilities in Field U , or other facilities around it•X,Y,Z is the reservoir from field P

Time

Data

High

Most likely

LOW DevelopmentDecision

P1

P2P3

Reserves for POP and POD/POFD

POD

• Reserves is calculated from the producing zone. If the predicted production time is limited by contract, therefore reserves calculation is counted untill the contract is over.

• Reserve Classification that used for POD Proposal is already using the classification for P1, P2 and P3. Reserves Calculation is referring to Iso-HPV (Hydrocarbon pore volume) map or Net Pay.

Reserves Calculation for POP dan POD/POFD

Reserves that is used to predict the production in POP/POD/POFD Proposal, should enter a risk factor in the calculation.

• POP (Put On Production) : 90% P1

• POD (Plan of Development) : Oil = 90% P1 + 50% P2 Pipe Gas = 90% P1 + 50% P2 LNG = 90% P1, 50%P2 can be used for domestic gas

• POFD (Plan of Further Development) from Produced Field : Oil = 90% P1 (remain reserves) + 50% P2 Pipe Gas = 90% P1 (remain reserves) + 50% P2 LNG = 90% P1 (remain reserves)

CHANCE OF GETTING ADDITIONAL RESERVES

Indonesia still have potentiality to gain additional reserves by:

• re-activating a number of ancient wells;• increasing production from fields with still

have low withdrawal rate (WR < 8%) or low recovery factor;

• Intensify the activities of getting additional reserves from marginal/small fields and brownfields;

• IOR/EOR Project.• Conducting unconventional oil/gas research

such as shale gas

CHANCE OF GETTING ADDITIONAL RESERVES

Source: SKKMIGAS

Chemical/Sulfactan

Steam Flood

Chemical/Sulfactan

Steam Flood

thank you

Ministry of Energy and Mineral ResourcesR&D Centre for Oil and Gas Technology

Republic of Indonesia LEMIGAS

[email protected][email protected][email protected]

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