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The Bakken Petroleum System of the Williston Basin Presented By: Steve Sonnenberg Colorado School of Mines Bakken Consortium

Williston Basin Production - American Association of ...education.aapg.org/bakken/BakkenWebinarSlides.pdf · the Williston Basin . ... Colorado School of Mines Bakken Consortium

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The Bakken Petroleum System of

the Williston Basin

Presented By:

Steve Sonnenberg

Colorado School of Mines

Bakken Consortium

The Bakken Petroleum System of the Williston Basin:

a Tight Oil Resource Play

Structure Base MissStephen A. Sonnenberg

Colorado School of Mines

WYOMING

SOUTHDAKOTA

NORTHDAKOTA

MANITOBASASKATCHEWAN

MONTANA

Limit of

Bakken Fm.

-5000

0 50 miles

Elm

Coulee

Cedar CreekAnticline

NessonAnticline

Sanish/Parshall

Area

ViewfieldArea

BillingsNose

B-SD Area

RoughRider

Blooming Prairie

Oil Shale Gas Hydrates

TightGas Sands;

CBM;Gas Shales

TightOil;

Heavy Oil;Bituminous

Sands

Oil Gas

Conventional Reservoirs:

Small Volumes,

Easy to Develop

Unconventional Reservoirs:

Large Volumes,

Hard to Develop

Huge

Volumes,

Difficult

to Develop

Incr

easi

ng P

rodu

ct P

rice

Impr

ovin

g Te

chno

logy

Province Resource Size

The Resource Pyramid

Oil Shale Gas Hydrates

TightGas Sands;

CBM;Gas Shales

TightOil;

Heavy Oil;Bituminous

Sands

Oil Gas

Conventional Reservoirs:

Small Volumes,

Easy to Develop

Unconventional Reservoirs:

Large Volumes,

Hard to Develop

Huge

Volumes,

Difficult

to Develop

Incr

easi

ng P

rodu

ct P

rice

Impr

ovin

g Te

chno

logy

Province Resource Size

The Resource Pyramid

Tight Oil Plays

A New Game

Blakey, 2007, <http://jan.ucc.nau.edu/~rcb7/namD360.jpg>

Bakken

Exshaw

Woodford

CottowoodCanyon

Leatham

Sappington

Antrim

New Albany

Woodford

Chattanooga

Sunbury

CanadianShield

Chattanooga

Percha

Pilot

Late Devonian-Early Mississippian black shales (360 Ma)

NISKU

CHARLES

MISSIONCANYON

LODGEPOLE

BAKKENTHREE FORKS

DE

VO

NIA

NM

ISS

ISS

IPP

IAN

MA

DIS

ON

GR

OU

P+++++

++++++++

+

BakkenPetroleum

System

NDIC (2010) estimated ultimate production

Bakken Petroleum System:

Bakken: 2.1 Billion barrelsThree Forks: 1.9 Billion barrels

0 50

MILES

Lower Bakken

Middle Bakken

Upper Shale Mbr.

Middle Siltstone Mbr.

Lower Shale Mbr.

WEST EAST

NESSON

ANTICLINE ANTELOPE

FIELD

XX

X

Isopach BakkenMeissner, 1978 after Sanberg, 1962

MTND

SD

CANADA

USA

Bakken Petroleum System

Reservoirs:

Middle Bakken & Three Forks

Source Beds:

Upper & Lower Bakken Shales

“What was made in the Bakken, stayed in the Bakken PS”

Meissner, 1978

“Relationship between source-rock maturity, hydrocarbon generation, geopressuring and fracturing suggest an opportunity in exploration for unrecognized and unlooked-for “unconventional” accumulations of potentially very large regional extent”

Bakken Petroleum System Basics

• Upper & lower black shales– „World Class‟ Source Rocks

• Hard, siliceous, pyritic, fissile, organic rich• TOC‟s as high as 40 wt% (average 11%)• High OM indicates anoxic conditions (amorphous-sapropelic OM)• HC Generation: 10 to 400 B bbl oil

• Middle member (target of horizontal drilling)– Dolomitic siltstone to a silty dolomite– Low porosity and permeability

• Upper Three Forks dolostones (target of horizontal drilling)

• Abnormal pressure and hydrocarbon generation (> 0.5 psi/ft)

Modified from LeFever, 2005

1970s-80sUpper Bakken Shale Play

Post 1987Horizontal Play

AntelopeField

Sanish, Three Forks& Bakken

1953

Elm Coulee2000-P

Horizontal Middle Bakken

Structure Bakken Fm.

Bakken

Three Forks

Parshall\SanishField - 2006

Ross

Bailey

Willmen

St. Demetrius

NessonAnticline“Rough Rider”

“Blooming Prairie”

Antelope Field

“Unusual Characteristics”

• Very high reservoir pressure• High productivity of several wells• Production associated with steepest

dip in central part of basin• Nebulous, ill-defined reservoir• Almost complete absence of water• Porosities 5-6%• Permeabilities < 0.1 md

Murray, 1968

Total GOR: 957 cf/bbl

WILLISTON BASIN - 3365 Grouped Wells (Daily Rates)

53 56 59 62 65 68 71 74 77 80 83 86 89 92 95 98 1 4 7 1012OIL=243,950,345 (BBL)

106

105

104

103

102

GAS=233,515,457 (MCF)

106

105

104

103

102

GOR (CUFT/BBL)

105

104

103

102

10

BO

PD

MC

FGP

D

100

1000

100000

1000000

100000

1000000

1000

100

Williston Basin Bakken and Three Forks Production

10000 100001000 G

OR

100

Antelope1953

Billings Nose1976

Horizontal DrillingUpper Bakken Shale

Billings Nose1987

Horizontal DrillingMiddle Bakken

Elm Coulee2000

Horizontal DrillingMiddle BakkenParshall Field

2006

Lear Pet Expl Parshall SD 1

Sec. 3-T152N-R90W

Lodgepole

Ba

kk

en

Upper Shale

Middle Mbr.

Lower Shale

Upper

Three Forks

“False Bakken”

Scallion

C

D

E

BA

F

Facies after Canter et al., 2008; LeFever, 2007; Berwick, 2009

TF-C

TF-D

UBS

LBS

TF-E

Factors Related to Bakken/Three Forks Oil Production

• Source beds - UB, LB; Reservoirs-MB, TF• Reservoir-favorable facies and diagenetic

history (matrix permeability)• Mature source rocks form continuous oil column

(pervasive saturation)• Favorable history of fracture development: folds,

faults, solution of evaporites, high fluid pressures, regional stress field (fracture permeability)

• Drilling and completion technology

Bakken Mudrocks

Kennedy F-32-24PSec. 24-149N-93W

AB

C

DE&F

False BakkenScallion

UBS

M-B

LBS

TF

LDGPL

10570

10575

10580

10585

10590

10595

10600

0 5 10 15 20

10506

10508

10510

10512

10514

10516

10518

10520

10522

0 5 10 15 20

Facies after Canter and Sonnenfeld, 2008; LeFever, 2007; Berwick, 2009

TF-C

TF-D

TF-E

Murray, 1968Comments on the Bakken shales:

“Any restricted reservoir in direct contact with either of the two shale units should be productive anywhere in the deeper part of the basin, regardless of structural position”

“One of the most important conclusions is the recognition that the upper and lower Bakken shale beds are supercharged oil shales and that they probably are the immediate source of most of the oil”

Upp

er S

hale

Low

er S

haleBraaflat Mineralogy

Sec. 11-T153N-R91W

CSM Qemscan

Depositional Setting:Lower and Upper Bakken Black Mudstone

Modified from Smith and Bustin, 1996; Meissner et al., 1984

Van Krevelen HI/OI

0

100

200

300

400

500

600

700

800

900

1000

0 20 40 60 80 100

OI (mg CO2/gm OC)

HI (m

g HC

/gm

OC)

0-40004001-60006001-80008001-1000010001-12000TYPE ITYPE IITYPE III

Type I

Type II

Type III

0

0.05

0.1

0.15

0.2

0.25

0.3

0.35

0.4

0.45

0.5

380 400 420 440 460 480 500

Tmax

Pro

du

ctio

n I

nd

ex 0-40004001-60006001-80008001-1000010001-12000

Immature

Oil Zone

Isopach Lower Bakken Shale

Isopach Upper Bakken Shale

High Paleogeothermal

Gradient Area

Lower Bakken Res

Upper Bakken Res

Limit MiddleBakken

Limit LowerBakken Shale

Limit Upper Bakken ShaleCCA

Structure Bakken Formation

50 miles

Resistivities Bakken Shales

Change in pore-

fluid volume

(porosity) and pore-

fluid species which

may accompany

hydrocarbon-

generation

(maturity) in source

rocks

Meissner, 1978

Water Wet

Oil Wet

2000 4000 8000

Modified from Meissner, 1978

• Bakken/Sanish/UTFabnormal pressured

• Regarded by Meissner (1978) to be due to hydrocarbon generation which results from excess volumes of oil in shales

FORMATION PORE-FLUID PRESSURE - psi

6000

14000

12000

10000

8000

6000

4000

2000

0

DE

PT

H -

FE

ET

Normal or Hydrostatic fluid

pressure based on average

Paleozoic Formation water

salinity of 325,000 ppm and a

related fluid pressure gradient

of 0.53 psi\ft

Lodgepole 0.46

Bakken/Sanish 0.73

Nisku 0.47

Mission Canyon 0.46

Kibby 0.47

Silurian 0.46

Formation fluid

pressure psi/ft

Isopach HILower Bakken Shale

Type II/IIIType I/II

HGG

Isopach HIUpper Bakken Shale

Type II/III

Type I/IIHGG

Bakken Facies

Isopach

Middle Bakken

Lear Pet Expl Parshall SD 1

Sec. 3-T152N-R90W

Lodgepole

Ba

kk

en

Upper Shale

Middle Mbr.

Lower Shale

Three Forks

“False Bakken”

Scallion

L-M

M-M

U-M

D

B

A

E-F

C

B - Bioturbated, argillaceous, calc. poorly sorted, vfg, sandstone/siltstone with helminthopsis/sclarituba.A - Intraclastic-skeletal lime wackestone, 1-4 ft thick.

D - Bioturbated, argillaceous, calc. poorly sorted, vfg, sandstone/siltstone with helminthopsis/sclarituba.E - Intraclastic-skeletal lime wackestone, 1-4 ft thick.

L1 – Siltstone, gray-green massive, bioturbated (Nerites ichnofacies), fossiliferous.

C - Rhythmic, varve-like, mm to cm laminated, well sorted, v.f.g. sandstone and siltstone with calcite cement, hummocks and wave ripples.

C - Rhythmic, varve-like, mm to cm laminated, well sorted, v.f.g. sandstone and siltstone with calcite cement, hummocks and wave ripples.

L2 - Interbedded dark-gray shale and buff, silty sandstone, moderate to intense bioturbation (Cruziana ichnofacies), fossiliferous.

A – Siltstone, gray-green, argillaceous, abundant bioturbation, Nerites & Phycosiphon.

D - Highest energy, coarsest grained alternating cross-bedded bioclast, v.f.g. sandstone.

B1 - Highest energy, coarsest grained alternating cross-bedded bioclast, v.f.g. sandstone.B2 - Muddy calcareous sandy/silty disturbed facies, synsedimentary microfaults, slumps.

L3 – Sandstone, upper & lower wavy to flaser silty sandstone, Skolithos ichnofacies. Middle coarse-grained, massive to xbedded.

B – Sandstone, fg, sharp basal contact, from base upwards, massive to xbedded to laminated. Rare Planolites.

F - Calcitic, whole fossil, dolo-to lime wackestones: fossil-rich beds.E - Thin-bedded dolo-mud/wackestone, more dolomitic.

A1 - Calcitic, whole fossil, dolo- to lime wackestones: fossil-rich beds.A2 - Thin-bedded dolo-mud/wackestone, more dolomitic.A3 - Thin organic-rich mudstone, gamma ray marker.

L4 – Interbedded dark-gray shale and buff, silty sandstone, coarsens upward, moderately bioturbated (Cruziana ichnofacies).

C – Siltstone, laminated, argillaceous, & vfg sandstone, bioturbated, soft sediment deformation. Phycosiphon, Planolites & Teichichnus.

F1 - Pyritic dolostones.A0 - Patterned pyritic dolostones.

L5 – Siltstone, gray-green, massive, mottled, dolomitic, Nerites ichnofacies.

MIDDLE BAKKEN LITHOFACIESNickel & Kohlruss, 2009 LeFever & Nordeng, 2008 Canter & Sonnenfeld, 2009 CSM, 2010

ts

SB

mfs

TST

LST

HST

Skeletal wackestone

Bioturbated siltsone,Vfg ss

Laminite, vfg ss-siltstone

X-bedded bioclast, SS

Thin bedded, dolo-mud, wackestone

Blakey, 2007, <http://jan.ucc.nau.edu/~rcb7/namD360.jpg>

WillistonBasin

CanadianShield

Late Devonian-Early Mississippian black shales (360 Ma)

Depositional Environment-Shallow Shelf

Erosion

XLayer-Cake Shelf Model:

high O2 high productivity

anoxic

rapid subsidence or fast rise in sea levelLBS silty

LBS A B C

D E

F UBS

NS

Uplift?

~ 50 m

Siliciclastic sediment input

slow subsidence or slow rise in sea level

carbonate production

sedimentation rates > rate of sea level rise

sedimentation rates < rate of sea level rise

anoxic

high O2

After Theloy, 2010

Simenson, 2010

Simenson, 2010

QEMSCAN ANALYSIS Middle Bakken

Simenson, 2010

Simenson, 2010

Modified from Whiting, 2010

Structure

Three Forks

50 Miles

Overview of Upper Three Forks

• Upper Three Forks Facies– Silty dolomite; highly deformed and brecciated: tidal mud

flat to sabkha – Silty dolomite, dolomitic siltstone, and shale (green)

deposited in tidal mud flat– burrowed dolomitic unit deposited in subtidal environment

• Sanish Sandstone– Fine-grained and burrowed– Locally developed– Sharp contact with upper Three Forks– Sharp contact with Lower Bakken Shale

Jorgenson 1-15H

Sec. 15-T148N-R96W

Jorgenson 1-15

0% 20% 40% 60% 80% 100%

10970

10972

10976

10979

10989

11000

11041

11045

11049

11053

11060

11068

11077

11082

QuartzFeldsparCalciteDolomitePyriteChloriteIllite

Jorgenson 1-15

0% 20% 40% 60% 80% 100%

10970

10976

10989

11041

11049

11060

11077

QuartzFeldsparCalciteDolomitePyriteChloriteIllite

Jorgenson 1-15

0% 20% 40% 60% 80% 100%

10970

10972

10976

10979

10989

11000

11041

11045

11049

11053

11060

11068

11077

11082

QuartzFeldsparCalciteDolomitePyriteChloriteIllite

XRDLodgepole

U Bakken

M Bakken

L Bakken

Sanish

Upper

Three

Forks

Modified from Berwick, 2009

Sanish(~5 ft)

UpperThreeForks

(~40 ft)

IntertidalMudflat

Intertidal-Supratidal

- Contact between Facies C and B. Bounding Discontinuity (Paleobathymetric shift)

- Contact between Facies D and C. Flooding Surface

Fresh Water Recharge

Hypersaline Sea Water Recharge

Saline Tidal flat-Sabkha (precipitation of evaporites)

Facies B

Intertidal - Supratidal

Fresh Surface Water Recharge (dissolution of

evaporites)

Fresh Water Recharge(dissolution of evaporites)

Hypersaline Water Recharge

10‟s of miles (?)

Desiccation features

Parallel Laminations

Algal structures/laminations

Facies D

Facies C

Facies B

12

12

1

2

* Not to scale

10‟s of feet (?)

Bi-directional cross-laminations

Uni-direction cross-laminations

Tidal Creek

Berwick, 2009

Isopach

Upper

Three Forks

Isopach

Lower Bakken

CI: 10 ft

Resistivity lines from Hester and Schmoker, 1985

50 Mi

Fractures

Origin of Bakken Fractures

• Folding and faulting• High fluid pressures• Solution of evaporites• Recurrent movement on

basement shear zones• Regional stress field with open

fracture direction

• Vertical fractures, bedding plane partings

(i.e., horizontal fractures) all play a role

Bakken & Three Forks Fractures

Working Hypothesis

Carus FeeUpper Bakken Shale

11293NDIC

Maxus Shapiro 13-3Sec. 3-T142N-R102W Little Knife Field

Narr and Burrus

Fidelity 43-28H DCRSec. 28-T154N-R92W

Nesson State 42X-36HSec. 36-T156N-R95WCarus Fee 21

Sec. 19-T147N-R96W

Regional Fractures

Summary

• Unconventional tight oil resource plays are „changing the game‟

• It all starts with good to excellent source beds• Source beds mature over large areal extent • Natural fracturing enhances tight reservoirs• Horizontal drilling and fracture stimulation

technology important in tight oil plays