Ute Mountain Ute Indian Reservation
Document Sample
Ute Mountain Ute Indian Reservation R18W
Cortez
General Setting Karle Key
Mine Xu
Xu
Xcu
n
R17W T
36
C anyo N
Xcu
McElmo
WIND RIVER 32
The Ute Mountain Ute Reservation is located in the northwest
INDIAN MABEL
RESERVATION
MOUNTAIN N
FT HALL I
IND RES Little Moude TA
ern portion of New Mexico and the southwestern corner of Colorado Mine Xcu
E
M
O
UN
UTE
T
35
N
UT PEAK
(Fig. UM-1). The reservation consists of 553,008 acres in Montezu W Y O M I N G EE
NG
PI BLACK
MOUNTAIN
N 666
R16W
T
R20W SL 35
ma and La Plata Counties, Colorado, and San Juan County, New R19W
N
Mexico. All of these lands belong to the tribe but are held in trust by NORTHWESTERN
SHOSHONI
Coche
HERMANO
T
34
Desert Canyon PEAK N MESA VERDE
IND RES
R14W
the U.S. Government. Individually owned lands, or allotments, are W NATIONAL
located at Allen Canyon and White Mesa, San Juan County, Utah,
GR
Marble
Towaoc
EA
SENTINEL PARK
Wash
T
SA
PEAK
LT
and cover 8,499 acres. Tribal lands held in trust within this area cov T
LA
er
Towaoc
KE
Riv
33 1/2
M
er 3,597 acres. An additional forty acres are defined as U.S. Govern THE MOUND R15W
N
ment lands in San Juan County, Utah, and are utilized for school pur
E
SKULL VALLEY
IND RES
TE
vajo
UNITAH AND OURAY
XA
poses.
Na
INDIAN RESERVATION
SP
S
W
AC
Ramona 789
I
The Allen Canyon allotments are located twelve miles west of
GOSHUTE
FIC
COLORADO
IND RES
T
UTAH
6-I
A
NC
33
Blanding, Utah, and adjacent to the Manti-La Sal National Forest. Chipeta
H
N
OI
U T A H
LP
TY
The White Mesa allotments are located nine miles south of Blanding,
r
ve
IPE
UN
Ri
TY
CO
LIN
C O L O R A D O
UN
E
Utah, on Utah Highway 47. These lands belong to known members
CO
666 R13 1/2W
A
41
UM
PAIUTE I R
os
A
EZ
V
AT
nc
of the Tribe or their heirs; however, the titles are held in trust for
Mancos
NT
Ma
PL
River TANNER MESA
MO
Mancos
T
LA
Farms
these individuals by the U.S. Government. The Ute Mountain Ute 32
E
Aztec Wash
W San Juan River N
W MONTEZUMA
R
COUNTY
Tribe also holds fee patent title to seven tracts of land located in Utah R20W R19W R18W R17W R16W
COLORADO
NEW MEXICO SAN JUAN COUNTY
and Colorado totaling 595,647 acres. PAIUTE I R Barker
D
UTE MOUNTAIN UTE Dome
T
The topography of the reservation varies from approximately INDIAN RESERVATION
EXPLANATION COLORADO
32
E
PAIUTE I R
Oilfield X Prospect N
4,600 feet near the Four Corners to approximately 10,000 feet at the
SOUTHERN UTE
IND RES
Gasfield cu- copper NEW MEXICO
KAIBAB
u- uranium Ute
peak of the Sleeping Ute Mountain. The eastern half of the reserva IND RES
NAVAJO INDIAN RESERVATION
Oil pipeline
W Sand and gravel pit M)
Dome
TAOS Gas pipeline ELIU
tion is characterized by a high mesa cut by the canyon of the Mancos
JICARILLA (H
INE
TAOS IND RES INDEX MAP
APACHE
Indian Reservation boundary EL
IND RES IND RES
PIP
W
CH
4-IN T
es
HAVASUPAI I R PICURIS
River and numerous side canyons. The western half of the reserva ES
tw
SAN JUAN I R IND RES IN
FM 31
at
O
er
SANTA CLARA POJOAQUE I R
0 10 MILES EAU
Ca
IR NAMBE I R
5 . BU
R N
tion, with the exception of the Sleeping Ute Mountain, is semi-desert
HOPI INDIAN SAN ILDEFONSO I R
ny
RESERVATION Horseshoe- U.S
on
TESUQUE I R
JEMEZ I R
0 5 10 20 KILOMETERS Verde-
HUALAPAI
IND RES COCHITI I R Gallop Gallop
grassland. NAVAJO
IND RES
ZIA
IND RES
SANTA DOMINGO I R
SAN FELIPE I R
NAVAJO I R SANTA ANA I R
R16W
The reservation ranges in elevations from about 4,600 feet along R15W
LAGUNA
RAMAH NAVAJO
SANDIA I R R14W
IND RES
ZUNI CANONCITO I R
the San Juan River near Four Corners (the junction of the States of IND RES ACOMA
IR
ISLETA
IND RES
Figure UM-2. Geographic map of the Ute Mountain Ute Indian Reservation.
Arizona, Utah, Colorado, and New Mexico) to 9,977 feet on Ute
LAGUNA I R
CAMP VERDE I R
A R I Z O N A
YAVAPAI I R
ALAMO NAVAJO
peak. Most of the western part of the reservation is semi-arid, eroded
PAYSON COMMUNITY I R
IND RES
grasslands with some “badlands” topography near the Utah boun FT APACHE
INDIAN RESERVATION
N E W M E X I C O
dary. North of the grasslands is the Sleeping Ute Mountain with a SALT RIVER I R
FT MC DOWELL
IND RES
cover of scrub cedar, oak, and juniper. The eastern and southern
SAN CARLOS
INDIAN RESERVATION
MESCALERO
IND
parts of the reservation consist of the deeply-cut canyons and mesas
GILA BEND GILA RIVER RES
IND RES MARICOPA IND RES
PAPAGO
IND RES IND RES
of Mesa Verde and Tanner Mesa, and is covered by scrub cedar and
juniper. PAPAGO
PASCUA YAQUI I R
The only paved highways in the reservation are U.S. Highways
INDIAN
RESERVATION
SAN XAVIER
IND RES
160 and 666 and State Highways 41 and 789 (Fig. UM-2). Two YSLETA DEL SUR I R
maintained gravel roads cross the reservation: one follows the Man
cos River Canyon to the eastern part of the reservation, then south Figure UM-1. Location of the Ute Mountain Ute Indian Reservation (modified after U.S.
ward toward Farmington and the other goes westward from Towaoc Department of the Interior, 1993).
to the Cache oilfield then on to Aneth, Utah. Other roads are gener
ally trails passable only to four-wheel-drive vehicles or pickup
trucks. reservation in New Mexico are the towns of Shiprock, 30 miles from
Towaoc, the only town on the reservation, is the site of the Ute Towaoc, and Farmington, 29 miles east of Shiprock.
Mountain Indian Agency and the residence of most of the people on
the reservation. Cortez, Colorado, 16 miles northeast of Towaoc,
serves as the principal market center for the area. South of the
UTE MOUNTAIN UTE RESERVATION Reservation Overview 1
COLORADO, NEW MEXICO
Geology structural platform between the Monument Uplift, about 40 miles the maximum dip is about 9 ½ degrees. Except for the south side, faults are downthrown to the north, while others are downthrown to the
The Ute Mountain Ute Indian Reservation is on the Four Corners to the west, and the San Juan basin immediately to the southeast. the flanks of the dome pass into a series of five anticlines, only south. Apparently the majority are high-angle normal faults. The two
platform of the Colorado Plateau, and most of it is underlain by Superimposed on the platform are several smaller structures that two of which extend into the reservation. A moderately sharp anti longest faults southeast of Southern Ute Dome have curved traces ow
gently dipping Mesozoic age sedimentary rocks (Fig. UM-3). give the reservation its own character; these are the Ute Dome, the cline plunges southeastward from McElmo Dome in the vicinity of ing to actual curves in the fault planes rather than to the effect of topog
Most of the rocks exposed on the Reservation are sandstones, Mesa Verde Basin, and the Hogback Monocline, and even more Ute Peak. It is asymmetric, with a steeply dipping southwest side. raphy on dipping fault planes. Two miles southwest of Southern Ute
shales, and mudstones of Cretaceous age; the oldest sedimentary locally, the McElmo Dome, the Barker Dome and Anticline, and A poorly defined anticline extends southwest from McElmo Dome Dome, two strike faults die out as small monoclinal flexures.
formation exposed is of Jurassic age and the youngest consolidated the Southern Ute Dome (Figs. UM-3 and UM-4). about 4 miles, almost parallel to a graben that lies to the north.
rocks are Tertiary. The oldest units crop out along the northern Ute Dome is probably entirely the result of injection of mag The total area affected by McElmo Dome and its satellitie anti
most boundary of the Reservation, and the exposed sedimentary ma and principally of three stocks at “The Knees,” Black Moun clines is about 20 miles east to west 41
112 111 110 109 108 107
EXPLANATION WYOMING WYOMING
41
and 10 miles north to south.
UTAH
rocks become progressively younger toward the south and east, re tain, and Ute Peak. The dome is nearly circular in plan and aver Monocline or steep limb of fold
COLORADO
0 8 16 32 48 64 Miles
flecting the higher topographic position of the Mesa Verde plateau. ages about 10 miles in diameter (Fig. UM-3). On its western side, Barker Dome and Anticline are on with direction of dip
INTA UPLIFT 0 8 16 32
U 48 64 80 96 Kilometers
The principal area of non-sedimentary rocks in the Reservation is the dome merges with west-and-southwest-plunging folds, and its the east flank of the Mesa Verde Basin, Crestal line of anticline, arch, uplift, up-
warp, or swell, with direction of plunge SCALE
the Ute Mountains, which are formed of Late Cretaceous or Terti western edge is poorly defined. The southwest flank of the dome at the east side of the reservation. The Troughal line of syncline, basin, or sag
AX
IA
L
VERNAL
ary igneous rocks. may be underlain by a large intrusive mass, and an irregular-shap dome is slightly elongated north and with direction of plunge
FO
south, and extends northward for sev High-angle fault, with downthrown side UINTA LD
BELT
Older sedimentary formations not exposed on the Reservation ed anticline that plunges westward from the northwest flank of the
but occurring in the subsurface include, in descending order, the dome may also be underlain by an igneous mass, at least in part. eral miles as the Barker Anticline. 40 Thrust fault, with updrawn side
R
40
MEEKER
IVE
LA S ARC
R
Kayenta Formation and Wingate Sandstone of the Glen Canyon Other folds along the western flank do not appear to be closely re Maximum closure is at least 200 feet. WHITE
COLORADO
Boundary of tectonic division
South Ute Dome is a small, nearly BASIN RIVER
UTAH
Group of Jurassic age; the Dolores (Chinle), Shinarump, and lated to igneous activity. They are associated with zones of frac UPLIFT
UG
Moenkopi Formations of Triassic age; the Cutler and Rico Forma turing that may be tectonic in nature. round dome about a mile wide, imme Uplift
PICEANCE
RIV E R
DO
PRICE
SAG
O
tions of Permian age; and the Paradox Formation of Pennsylvanian The Mesa Verde Basin is a broad downwarp that is generally diately southeast of Barker Dome (Fig. CA
D
CA
W ELL
RA
Basin RB
LO RB
LEY
N SA ON O BA ON
UM-3). Its eastern and southern flanks G ER C
age. The Paradox Formation, characterized by its content of salt reflected by the surface topography of Mesa Verde and occupies A SI DA
VAL
N L
EN
EL S
E
JU
RE
and gypsum, is significant because it is the producing horizon for most of the area between Ute Dome and the Hogback Monocline; are formed by a bend in the Hogback NC
G
TI BASIN
T LE
LK
FA
39 O
E
Monocline, and its western flank is GR.
CAS
N 39
RA
oil wells in the northwest corner of the reservation. In that area it the center of the basin coincides closely with the lowest part of the
GREEN
UP
RIVER UN BE JUNCTION
PA
COLORADO ROCKIES
N
NC
US
LIF
formed by the eastern limb of a south CO
SA
lies at depths of about 5,700 to 6,000 feet below the surface. Mesa Verde Upland in T 32 N, R 15 W. Structural closure on the RA M H
T
PA
EA
Structure basin is probably on the order of 200-300 feet. Structural closure easterly plunging syncline that sepa DO
HG
RE M
O
GU
NN
LA SAL
AT
DOME
N
rates South Ute Dome from Barker FA
CA RE BE
UP IS
In broad aspect the Ute Mountain Ute Indian Reservation lies on a is limited due to the close proximity of the basin to the Hogback X TR
D OL
ON MOAB
PI EF LT
FO
UL AN
LI O GUNNISON
TO
OR
PL
LD
FT SE UP
L
Dome.
ES
LI
109 00' 45' Monocline. T D FO SA
G
FT
GH
Steeply dipping normal faults oc LD
HE
30'
The Hogback Monocline trends BE
N
50
McELMO
PE
HI
67
cur in the Ute Mountains area on the
RY
DOME northeasterly across the southeast part of 38
LT
HE
YON SLO
38
NR
600
SA
0
south, southwest and northwest flanks
Y
the reservation, where it is reflected in SAN
R IVE
DO
NJ
WILSON
ME
DOME
CI
of Ute Dome, and to the southwest
T U PW AR
UA
BA
RC
S
small hogbacks formed by steeply dipping
LE
S IN
C AN
ABAJO
NS
JICO
JUAN
CL
00
flank of McElmo Dome. The greatest
DOME
60 108 15' DOME
sandstone beds of the Pictured Cliffs
IFF
AG
R
NEEDLE
E
ITE
SU
IV
LA PLATA DOME
concentration of faults is on the north
R
EN
PL
KAIPAROWITS BLANDING
Sandstone (Fig. UM-3). The dips in this
DOME
WH
IFT
DOME
NU M
37 15' CORTEZ
west flank of Ute Dome. Two sets of
AR
UTE CH
R
area are mostly between 20 and 30 de BASIN
00
U
E
50
DOME S LE
RIV
BASIN ER
DURANGO
MO
TA
grees. The change in dip toward the San faults appear to have formed simulta ORAD O RN
UTE
DOME
OL
CO RM
C
NAVAJO
SENTINEL PEAK 400
0
Juan Basin is relatively abrupt, and only a neously in this vicinity; one set strikes 37 FO
UR
TF
O DOME UTAH 37 COLORADO
AS T KAIBAB S YNCL IN E
E
ARIZONA
LA
NEW MEXICO
DOME PIUTE
nearly west, the other northeast. The
ECHO C I F FS U
OLUETO
P
short distance from the steepest part of the
CARRIED
FOLDS
C HAM A
SAG
DOME
TYENDE
N
KAI BA
A
monocline the dips in the basin are only 1 west-striking faults parallel west-trend KAIBITO SADDLE
RED ROCK
FARMINGTON SA
N JU
SAN JUAN
5000
L
UTE MOUNTAIN INDIAN RESERVATION
or 2 degrees. On the northwest side of the ing folds and have displacements that SADDLE BENCH
3000 PRESTON
rarely exceed 30 feet. The northeast-
BASIN
monocline the beds flatten somewhat
PL
D EF
BENCH
UP
trending faults appear to be extensions BASIN
IF
more gradually to an essentially horizon
NEW MEXICO
LI
T
IANC
MESA VERDE T
ARIZONA
BLACK MESA
F
BASIN
tal position, except at the Southern Ute of a zone of faulting that cuts the
AR
E
36
IUCIMIENTO UPL
37 00'
C
southwest flank and the central part of 36
H
BARKER
DOME and Barker Domes (Fig. UM-3). Between CAMERON
SOUTH
UTE the two areas of nearly horizontal beds, McElmo Dome. This zone curves to a NIN
O BENCH BASIN CH
DOME CO AG
nearly east strike and continues toward CO LIENT O
IFT
EXPLANATION which are only 2 to 4 miles apart, there
UPLI FT
H
SA
G
Cortez, Colorado. The faults along
-1000
SLOPE
are several thousand feet of structural re
0
300 W GALLUP
RO U
UP LIT
T
UL CO
AT
this zone form a graben on the south ZU
EL
2000
Structure contours - drawn on GALLUPE
TL
2000
KI
lief.
FA UER
MONOCLINE
TB
base of Dakota Sandstone. BE SAG NI
1000 UP
E
P
NC
Contour interval 250 feet
west flank of McElmo Dome and have
ND
0
LI
T
H
The McElmo Dome is immediately FT
RA
FLAGSTAFF
G
Near vertical fault
NDE
north of the Ute Mountains, and only the displacements of as much as 180 feet, 35 WINSLOW ACOMA
50
Anticline - showing plunge OL 35 ALBUQUERQUE
37
K
ORADO
C
the greatest known in the Ute Moun
AC
RIO GRA
Syncline - showing plunge southernmost part of it lies within the res MOGOLL
HOLBROOM
SAG
GB
tain area. ON SLO
HO
UP ERO
ervation (Fig. UM-3). Its structure is well
T
0 5 10 15 MILES
PE
LIF
RI
C
Most of the faults in this area are
LU
VE
IO
R
R
0 5 10 15 KILOMETERS exposed in McElmo Canyon, which cuts
through its southern flank. The dome is concentrated on a bend in the Hogback 112 111 110 109 108 107
Figure UM-3. Tectonic map of the Ute Mountain Ute Indian Reservation. Structure contour Monocline south of Southern Ute
lines are drawn on the base of the Dakota Sandstone (modified after Anderson, 1995). asymmetric, steepest on the south where Figure UM-4. Tectonic divisions of the Colorado Plateau (modified after Kelley, 1955).
Dome. The strikes of these faults
range from N 70 W to N 90 W. Some
UTE MOUNTAIN UTE RESERVATION Geology Overview 2
COLORADO, NEW MEXICO
Basin Provinces
(SOUTHWEST AND WEST) (NORTHEAST AND EAST
110 108 EXPLANATION SAN RAFAEL SWELL NORTHERN PARADOX BASIN UNCOMPAHGRE
The Ute Mountain Ute Indian Reservation is located on two
AND HENRY MOUNTAINS AND BOOK CLIFFS PLATEAU)
Paradox Basin USGS designated Basin Provinces. The northwestern part of
M.Y. WASATCH FORMATION 1800'
Province the reservation is located in the Paradox Basin Province and TERTIARY
66
San Juan Basin the southeast part is located in the San Juan Basin Province FARRER FORMATION 1000'
Province
(Fig. UM-5). (ERODED) MESAVERDE GROUP
NELSEN FORMATION 600'
SEGO SANDSTONE 50-200'
UNAMED BEDS ? BUCK TONGUE 0-200'
Ute Mt. Ute Indian MESAVERDE FORMATION 300'
38 38 CASTLEGATE SANDSTONE 0-300'
}
Reservation
Paradox Basin Province MASUK
CRETACEOUS
MBR 700' BLACKHAWK
UPPER (TYPE AREA) EQUIVALENT MANCOS SHALE
EMERY SS 300' 4000'
The Paradox Basin Province is in southeastern and south-cen BLUE GATE SHALE MEMBER
tral Utah and southwestern Colorado and encompasses much 1500'
?
JUANA LOPEZ MEMBER ("FERRON MARKER")
UT of the area from latitude 37° to 40° north and from longitude FERRON SS
0-400'
CO TUNUNK SHALE MEMBER 600'
GREENHORN LIMESTONE MEMBER
108° to 114° west (Fig. UM-5). It includes almost all of the DAKOTA SANSTONE 50-200'
AZ NM Paradox Basin, the Uncompahgre and San Juan Uplifts, the LOWER BUCKHORN COL CEDAR MNT FORMATION 100-250' BURRO CANYON FORMATION
138 ?
San Rafael, Circle Cliffs, and Monument Uplifts, the Kaipar UPPER
MORRISON FORMATION BRUSHY BASIN MEMBER
}
TIDWELL MEMBER 600-800' SALT WASH MEMBER
owits and Henry Mountains Basins, and the Wasatch and SUMMERVILLE FORMATION
JURASSIC
CURTIS FORMATION 0-200' CURTIS EQUIV. MOAB TONGUE WANAKAH FM
Pausaugunt Plateaus (Fig. UM-4). Maximum dimensions of MIDDLE SAN RAFAEL GROUP ENTRADA SANDSTONE 100-500' SLICK ROCK MEMBER ENTRADA SANSTONE
the province area are approximately 280 miles long and 200 CARMEL FORMATION 100-300' DEWEY BRIDGE MEMBER
SCALE
miles wide. It covers an area of about 33,000 square miles. GLEN CANYON NAVAJO SANDSTONE 0-450'
LOWER
0 25 50 miles The maximum thickness of Phanerozoic sedimentary rocks 205 WINDGATE SS 300'
GROUP KAYENTA FORMATION 100-250'
110 108
ranges from 5,000-8,000 feet in the central part of the prov CHURCH ROCK MBR
OWL ROCK MBR ?
ince to more than 15,000 feet in the Paradox Basin, Kaiparo UPPER PETRIFIED FOREST MBR CHINLE FORMATION 300-600'
TRIASSIC
MOSS BACK MBR
wits Basin, and Wasatch Plateau. Rocks in the Paradox Basin
MONITOR BUTTE MBR
Figure UM-5. Location of the Paradox Basin Province and the San Juan Basin SHINARUMPCGL
MIDDLE
Provinces (modified after Gautier, et al., 1996) range in age from Precambrian through Tertiary (Fig. UM-6). MOODY CANYON MBR
TORREY MBR
? PARIOTT MBR
MOENKOPI FORMATION 0-800' HOSKINNINI MBR SEWEMUP MBR
Most of the production in the province has been from po LOWER SINBAD LS MBR
BLACK DRAGON MBR
?
SO PARADOX ALI BABA MBR
TENDERFOOT MBR
NW SE rous carbonate buildups (mainly algal 240 OCHOAN
A A' GUADALUPIAN
180 MILES (290 KM) mounds) around the southwestern shelf LEONARDIAN WHITE RIM SS 0-500'
PERMIAN
EAST FLANK OF SHAFER TRAIL DOVE CREEK DURANGO
margin of the Paradox Basin. The giant ORGAN ROCK FORMATION 0-400'
CEDAR RIM SS 0-700' CUTLER FORMATION
SAN RAFAEL SWELL MOAB AREA AREA AREA Aneth Field, with more than 1 BBOIP ac WOLFCAMPIAN OR GROUP
(near I-70) (projected) UTAH | COLORADO LOWER CUTLER 0-1500' 0-8000'
1500
FERRON SANDSTONE MEMBER JUANA LOPEZ MEMBER
counts for as much as two-thirds of the pro 290 ?
ven resources in the province, and other VIRGILIAN
HONAKER TRAIL FORMATION
MISSOURIAN
PENNSYVANIAN
4000
CRETACEOUS MANCOS SHALE
fields in this primarily stratigraphic play 0-3000'
ISMAY
?
CEDAR MOUNTAIN FORMA
TION DAKOTA SANDSTONE K (Porous Carbonate Buildup Play, 2102) ac DESERT CR
PRODUCTION INTERVALS
BURRO CANYON FORMATION DESMOINESIAN HERMOSA FORMATION CANE CR CYCLE OF AKAH
count for much of the rest. Most of the oth OR GROUP THE ALKALI GULCH
INTERVAL BARKER CR
PARADOX FORMATION
(SALT)
0-2000'
MORRISON FORMATION er plays have a strong structural compo PINKERTON TRAIL FM 0-300'
(0-15,000' (Incl. salt flowage)
JURASSIC ATOKAN
1000
SUMMERVILLE FM.
?
J-5 MOAB MBR. WANAKAH FM.
? nent, particularly the Buried Fault Blocks, MORROWAN
MOLAS FM 0-100'
3000 ?
JUNCTION CR. SS. 330 CHESTERIAN
ENTRADA SANDSTONE
J-3 ? ?
Older Paleozoic (2101), Fractured Interbed
J-5 ?
MISS.
SLICK ROCK MBR. ? MERAMECIAN
SAN RAFAEL GP.
? ?
CUR
TIS F
OR MATIO
N DEWEY BRIDGE MBR.
(2103), and Salt Anticline Flank (2105)
J-2 OSAGEAN REDWALL LIMESTONE 500-800'
LEADVILLE LIMESTONE 0-500'
TONE
MEL
FO
NAV
RMA
TION
AJO S
ANDS J-3 Plays. The Permian–Pennsylvanian Mar 360
KINDERHOOKIAN
CAR DOLORES QUARY LIMESTONE 100'
NTA F
ORMA
TION FORMATION ginal Clastics Play (2104), Permo-Triassic UPPER ELBERT FORMATION 250' UPPER MBR
DEV.
KAYESTO
NE MC CRACKEN SS MBR
2000 AND STONE Unconformity Play (2106), and Cretaceous
PAG
ES
TE SAND MIDDLE ANETH FORMATION (SO. PARADOX)
WINGA 0-200'
GLEN CANYON GP.
TR-3
MATIO
N TRIASSIC
Sandstone Play (2107), as well as the hypo 410
LOWER
E FOR J-O
SILURIAN
CHINL thetical Lower Paleozoic/Proterozoic Play
500
435
FEREN
TIATED ORDOVICIAN
TR-3
KS
UNDIF (2403) which is described in Northern Ari 500 LYNCH DOL 0-600' ?
ROC UPPER
1000 N
ERM
IAN Vert. exag.=X146
zona Province (024), are combinations of MAXFIELD LS - MUAV LS 0-500' IGNACIO QTZITE
CAMBRIAN
ATIO E R TR-1 P
ORM MB
PI F ME
NKO NE ANGEL SH 0-400'
MOE
IME
STO C.M. MOLENAAR both structure and stratigraphy. The Frac MIDDLE
OPHIR SH - BRIGHT
EATS SS 100-300
'
DL TIC QTZITE - TAP
BA TIN
SIN
tured Interbed Play (2103) is an unconven
tional, continuous-type play. LOWER
570
0 0 PRECAMBRIAN GRANITIC AND HIGH-RANK METAMORPHIC ROCKS
ET M
Figure UM-7. Cross Section across the Paradox basin showing generalized stratigraphic relations of
Triassic, Jurassic, and the lower part of Cretaceous formations (modified from Molenaar, 1981). Figure UM-6. Correlation Chart for rocks of the Paradox Basin and vicinity (modified after Molenaar, 1987).
UTE MOUNTAIN UTE RESERVATION Paradox Basin Province 3
COLORADO AND NEW MEXICO
San Juan Basin Province northeast part of the structural basin where the Upper Devonian Elbert For ceous sandstones of the central basin is produced from
mation overlies Precambrian basement rocks. Elsewhere in the province, AGE FORMATION OF GROUP
stratigraphic traps. Around the flanks of the basin, some SW NE
The San Juan Basin Province incorporates much of the area from latitude 35° Cambrian, Mississippian, Pennsylvanian, or Permian rocks may overlie the of the same Cretaceous units produce oil on many of the
San Jose Formation
to 38° north and from longitude 106° to 109° west (Fig. UM-5) and compris Precambrian. structures. TERTIARY Nacimiento Formation
es all or part of four counties in northwest New Mexico and six counties in Plays were defined primarily on the basis of stratigraphy because of the Seven conventional plays were defined by the USGS
Ojo Alamo Sandstone
southwestern Colorado. It covers an area of about 22,000 square miles. strong stratigraphic controls on the occurrence of hydrocarbons throughout and are individually assessed in the province: Porous Car
Almost all hydrocarbon production and available subsurface data are re the province. In general, the plays correspond to lithostratigraphic units con bonate Buildup (2201), Marginal Clastics (2203), Entrada Kirtland Shale (Farmington Sandstone Member)
stricted to the San Juan Basin. Also included in the province, but separated taining good quality reservoir rocks and having access to source beds. In the (2204), Basin Margin Dakota Oil (2206), Tocito/Gallup Fruitland Formation
from the structural and topographic San Juan Basin by the Hogback Mono central part of the basin, porosity, permeability, stratigraphy, and hydrody Sandstone Oil (2207), Basin Margin Mesaverde Oil
Pictured Cliffs Sanstone
cline and Archuleta Arch, respectively, are the San Juan Dome and Chama namic forces control almost all production, whereas around the flanks, struc (2210), and Fruitland-Kirtland Fluvial Sandstone Gas
Lewis Shale
CRETACEOUS
Basin, which contain sedimentary sequences similar to those of the San Juan ture and stratigraphy are key trapping factors. Although most Pennsylvani (2212) Plays. The Porous Carbonate Buildup Play (2201)
Cliff House Sandstone
LATE
up de
Basin (Fig. UM-4). In much of the San Juan Dome area (Fig. UM-4) the an-age oil and gas is on structures around the northwestern margin, it com is assessed as part of play 2102 in the Paradox Basin; simi
ro r
G ave
Menefee Formation
sedimentary section is covered by variable thicknesses of volcanic rocks sur monly accumulates only in highly porous limestone buildups. Jurassic oil on lary, Permian–Pennsylvanian Marginal Clastics Gas Play
es
Point Lookout Sandstone
M
rounding numerous caldera structures. The stratigraphic section of the San the southern margin of the basin is stratigraphically trapped in eolian dunes (2203) is assessed as part of play 2104 in the Paradox Ba
Juan Basin attains a maximum thickness of approximately 15,000 feet in the at the top of the Entrada Sandstone. Almost all oil and gas in Upper Creta sin. Upper Mancos Shale
Gallup Ss. (Torrivio Mbr.) Tocito Ss. Lentil
A SAN JUAN BASIN
SOUTH STRATIGRAPHIC CROSS SECTION NORTH A' Lower Mancos Shale Greenhorn Limestone
Dakota Sandstone
KIRTLAND SHALE FM MAESTRICHTIAN Figure UM-9. EARLY Burro Canyon Formation
FRUITLAND FM Schematic north-
SECTION REMOVED BY LATE PICTURED CLIFFS SS south cross section Morrison Formation (Todilto Limestone Member)
TERTIARY TO QUATERNARY EROSION of Cretaceous JURASSIC Wanakah Formation
stratigraphy in
Entrada Sandstone
northwest New
LEWIS
CLIFF HOUSE SS Mexico (modified TRIASSIC Chinle Formation
SHALE CAMPANIAN after Molenaar,
De Chelley Sandstone
1973,1983 a,b).
Organ Rock Shale
Cutler
MESAVERDE PERMIAN
UPPER CRETACEOUS
MENEFEE FM Group Cedar Mesa Formation and related rocks
GROUP
POINT LOOKOUT SS Halgaito Formation
Rico Formation
Honaker Trail Formation
Hermosa
CREVASSE UPPER MANCOS SHALE SANTONIAN Paradox Formation and related rocks
PENNSYLVANIAN Group
CANYON FM Figure UM-8. Pinkerton Trail Formation
BORREGO PASS SS Geochronologic
Molas Formation
chart for the San
DILCO MEMBER CONIACIAN Juan Basin MISSISSIPPIAN Leadville Sandstone
MEMBER A TOCITO SANDSTONE
TORRIVIO B
Province (modified Ouray Limestone
after Gautier, et al., DEVONIAN
GALLUP Elbert Formation
1996).
SANSTONE C
JUANA LOPEZ MBR. TURONIAN CAMBRIAN Ignacio Quartzite
LOWER MANCOS
D SHALE
GREENHORN LS MBR PRECAMBRIAN
E Eight unconventional plays were also assessed: five continuous-type plays and
CENOMANIAN
F three coal-bed gas plays. Continuous-type plays are Fractured Interbed Play(2202),
DAKOTA SANDSTONE Dakota Central Basin Gas (2205), Mancos Fractured Shale (2208), Central Basin Me
saverde Gas (2209), and Pictured Cliffs Gas (2211) Plays. Also present is the continu
non-marine ss/sh estuarine ss (reservoir) ous-type Fractured Interbed Play (2103) which is described and assessed in Paradox
Basin Province (021). Coal-bed gas plays are San Juan Basin– Overpressured (2250),
shoreface sandstone muddy estuarine ss (largely non-reservoir)
San Juan Basin–Underpressured Discharge (2252), and San Juan Basin – Underpres
open marine shale estuarine open marine shale sured (2253).
marine limestone braided-fluvial sanstone
UTE MOUNTAIN UTE RESERVATION San Juan Basin Province 4
COLORADO, NEW MEXICO
TYPE LOGS ? HALGAITO
LOG 1 DAKOTA LOG 2
CRET.
FORMATION
SANDSTONE
Ute Mountain Ute Indian Reservation BURROW CANYON RICO
Gamma Ray FORMATION FORMATION
Two logs were chosen to represent the stratigraphy of the Ute Mountain Ute Gamma Ray
LEWIS
Indian Reservation. Cretaceous (upper Dakota-Lewis Shale) is shown in Log 1.
SHALE Resistivity
The Devonian-Cretaceous (lower Dakota) are shown in Log 2. The locations of Resistivity
these wells are shown in Figure UM-10.
MORRISON
FORMATION HONAKER
TRAIL
JURASSIC
FORMATION
Well 1:
Location: Sec 16, T32N, R12W, San Juan County, New Mexico
(from Molenaar and Baird, 1989)
CLIFF HOUSE WANAKH FM.
Well 2: SANDSTONE
Location: Sec 18, T36N, R14W, Montezuma County, New Mexico ENTRADA SS.
(from Molenaar and Baird, 1989 MENEFEE WINGATE SS.
FORMATION
VERTICAL SCALE POINT
LOOKOUT
0
SANDSTONE CHINLE
PRODUCING FORMATIONS
PENNSYLVANIAN
100 FORMATION
TRIASSIC
PARADOX
200 FORMATION
CRETACEOUS
AND
300
RELATED
400 ROCKS
500 feet
WELL 2
MANCOS
SHALE
ORGAN
ROCK
FORMATION
UTE MOUNTAIN UTE INDIAN RESERVATION
PERMIAN
JUANA CEDAR PINKERTON
WELL 1 LOPEZ MESA TRAIL
MEMBER SANDSTONE FORMATION
UT CO
MOLAS FM.
AZ NM
DEVONIAN MISS.
LEADVILLE
LIMESTONE
HALGAITO
FORMATION
OURAY FM.
UPPER MBR.
DAKOTA ELBERT FM.
Figure UM-10. Location of wells. SANDSTONE McCRACKEN SS.
IGNACIO QUARTZITE
UTE MOUNTAIN UTE RESERVATION Type logs for the Ute Mountain Ute Indian Reservation 5
COLORADO, NEW MEXICO
Play Types
Table 1: Play Summary Chart Conventional Plays- Discrete deposits, usually bounded by a downdip water contact, from which oil, gas or NGL can be extracted using traditional development practices, including
The United States Geological Survey identifies several petroleum plays in the San Juan and Paradox Basin Provinces production at the surface from a well as a consequence of natural pressure within the subsurface reservoir, artificial lifting of oil from the reservoir to the surface where applicable, and
and classifies them as Conventional and Unconventional. The discussions that follow are limited to those with direct the maintenance of reservoir pressure by means of water or gas injection.
significance for future petroleum development in the Ute Mountain Ute Indian Reservation. Unconventional Plays- A broad class of hydrocarbon deposits of a type (such as gas in “tight” sandstones, gas shales, and coal-bed gas) that historically has not been produced using
traditional development practices. Such accumulations include most continuous-type deposits
Reservation: Ute Mountain Ute Total Production
( by Province-1996) Paradox Basin San Juan Basin Undiscovered resources and numbers of fields are
Geologic Province: Paradox and San Juan Basins for Province-wide plays. No attempt has been made
Oil: 606,411 MBO 202,839 MBO
Province Area: Paradox Basin (33,000 sq. miles), San Juan Basin (22,000 sq. miles) to estimate number of undiscovered fields within the
Gas: 1,328,000 MMCFG 2,356,849 MMCFG
Reservation Area: 864 sq. miles (553,008 acres) Ute Mountain Ute Indian Reservation.
NGL: 66,206 MBNGL 39,074 MBNGL
USGS Undiscovered Accumulations > 1 MMBOE Play Probability Drilling depths
Play Type Description of Play Oil or Gas Known Accumulations Pay Thickness Porosity/Permeability
Designation Field Size and Number (chance of success) (min., mean, max.)
Field Size (median, mean)
Porous Carbonate Buildup Gas (10 BCFG, 131 BCFG)
Mounds of algal limestone in the Gas
Play Paradox Formation of the Hermosa Both Gas (448,740 MMCFG) Oil (4 MMBO, 6.3 MMBO) (4000, 6000, 14000)ft
2102 (Paradox) Oil (521,090 MBO) No. of Undiscovered Fields (min., median, max., mean) 1 10-50 feet 5-20%/9.1mD
Oil
1 2201 (San Juan) Group. Gas (3, 7, 15, 7.8) (2500, 6000, 14000)ft
Oil (10, 20, 50, 24.2)
Field Size (median, mean)
Tocito - Gallup Gas (30 BCFG, 38.0 BCFG) Gas
Lenticular sandstone bodies of
Sandstone Oil Play Upper Cretaceous Tocito and Gallup
Both Gas (199,800 MMCFG) Oil (4 MMBO, 6.3 MMBO)
1 (4000, 6000, 8000)ft <50 feet
4-20%/0.5-150mD
2207 Oil (174,135 MBO)
2
No. of Undiscovered Fields (min., median, max., mean) Oil
Sandstones.
Gas (1, 2, 5, 2.4) (1000, 5000, 8000)ft
Oil (2, 5, 8, 5.0)
Mancos Fractured
Shale Play 2208 Fractured organic rich marine Oil Gas (94.42 BCFG, est. mean) Oil Fracture Porosity/
Mancos Shale. Oil (188.85 MMBO, est. mean) N/A 1 Highly Variable Unlimited Permeability
3
(1000, 3000, 7000)ft
Central Basin Mesa-
verde Gas Play 2209
Sandstone buildups associated
N/A Gas
with stratigraphic rises in the Upper 1
Gas Gas (7,000 BCFG) (1000, 2600, 5000)ft 20-200 feet
4
Cretaceous Point Lookout and Cliff 10%/<2mD
House Sandstones.
Basin Margin Mesa- Intertonguing of porous marine sand-
stone at the base of the Upper Field Size (median, mean) Oil
verde Oil Play Cretaceous Point Lookout Sandstone Oil
Gas (7.8 BCFG, est. mean) Oil (2 MMBO, 1.9 MMBO) (300, 2000, 4000)ft 10-30 feet
2210 Oil (7.8 MMBO, est. mean) 0.8 23%/6mD
No. of Undiscovered Fields (min., median, max., mean)
5
with the organic-rich Upper Mancos
Shale. Oil (1, 5, 10, 4.2)
Basin Margin Dakota Field Size (median, mean)
Gas
Gas (10 BCFG, 12.1 BCFG)
Oil Play Mostly upper marine part of the Gas (62,100 MMCFG) Oil (2 MMBO, 2.8 MMBO)
(1000, 2000, 2000)ft
2206 Dakota Sandstone. Both Oil (22,8559 MBO) 1 Oil 10-100 feet
No. of Undiscovered Fields (min., median, max., mean) <20%/0.55-400mD
6 Gas (1, 2, 5, 2.4)
Oil (5, 10, 20, 11.1)
(600, 2000, 5000)ft
Dakota Central Basin
Coastal marine barrier-bar sand-
Gas Play 2205 stone and continental fluvial sand- Gas
Gas Gas (8211.28 BCFG, est. mean) N/A 1
stone units, primarily within the (5000, 6900, 8000)ft 30-70 feet 5-15%/0.1-0.25mD
7 transgressive Dakota Sandstone.
Buried Fault Blocks Field Size (median, mean)
Gas
Older Paleozoic Play Accumulations of oil in fault blocks Gas (59,518 MMCFG)
Gas (20 BCFG, 30.7 BCFG)
Oil (4 MMBO, 7.3 MMBO) (6000, 9000, 15000)ft 39.4 feet
Both 1
2101 involving pre-Pennsylvanian rocks. Oil (53,700 MBO) No. of Undiscovered Fields (min., median, max., mean) Oil 5-25%/<0.01-272mD
8 Gas (1, 4, 12, 5.1) (6000, 9000, 15000)ft
Oil (1, 4, 14, 5.1)
Fractured Interbed Play Gas
(hyopothetical, continuous) Fractured organic rich dolomitic Gas (193.86 BCFG, est. mean) (8000, 9000, 10000)ft
2103 Both N/A 1 Oil <20 feet 1-5%
shale and mudstone. Oil (242.32 MMBO, est. mean)
9 (8000, 9000, 10000)ft
Permian-Pennsylvanian Field Size (median, mean)
Gas
Gas (7 BCFG, 9 BCFG)
Marginal Clastics Play Porous and permeable sandstone Gas (7.0 BCFG, est. mean) Oil (1 MMBO, 1.3 MMBO)
(3000, 7000, 20000)ft
2104 intervals within the Permian Both Oil (2.3 MMBO, est. mean) 0.8 Oil N/A N/A
10 Cutler Formation. No. of Undiscovered Fields (min., median, max., mean)
(3000, 4500, 7000)ft
Gas (1, 6, 15, 5.5)
Oil (1, 2, 4, 1.8)
Conventional play type Unconventional/Hypothetical play type
UTE MOUNTAIN UTE RESERVATION Play Summary Table 6
COLORADO and NEW MEXICO
Porous Carbonate Buildup Play kerogen from terrestrial plant material in black shale source rocks. are the Barker Creek, Akah, Desert Creek, and Ismay Stages (Fig. UM- Creek is bounded by the Chimney Rock and Gothic Shales
(USGS Designation 2102, 2201) Timing and migration: In the central part of the San Juan Basin,
13). which represent transgressions (Fig. UM-13). Growth of the
Pennsylvanian sediments entered the thermal zone of oil generation The Barker Creek Stage has a gross thickness of 500 feet. It is a Desert Creek carbonate bank occurred during slow subsidence
General Characteristics during the Late Cretaceous to Paleocene, and the dry gas zone during fossiliferous, algal, dolomitic limestone with vuggy secondary dolo of the Paradox Basin. Source rocks for hydrocarbons are the
The Porous Carbonate Buildup Play in the Paradox and San Juan Basin the Eocene to Oligocene. It also is probable that Pennsylvanian source mite. Most reservoir rock is algal, dolomitic limestone with enhanced Chimney Rock and Gothic Shales.
Provinces (Fig. UM-11) is primarily a gas play and is characterized by rocks entered the zone of oil generation during the Oligocene porosity and permeability due to dolomitization and weathering. The The Ismay Stage is divided into lower and upper units.
oil and gas accumulations in mounds of algal (Ivanovia) limestone as throughout most of the Four Corners Platform. Updip migration and Barker Creek was deposited on paleostructural features related to the In the lower unit, bounded by the Gothic and Hovenweep
sociated with organic-rich black shale rimming the evaporite sequences local migration from laterally equivalent carbonates and shale beds in Hogback Lineament. Shales, oil is produced from algal carbonate mound buildups.
of the Paradox Formation of the Hermosa Group (Fig. UM-12). Most areas of favorable reservoir beds predominate, and remigration may The Akah Stage is not considered to be an exploration objective The upper unit is bounded by the Hovenweep and Boundary
developed fields within the play produce from combination traps in the have occurred in areas of faulting and fracturing. within the reservation because salt and anhydrite deposition was Butte Shales. Production there is from algal or fossiliferous
Paradox Basin Province. dominant during this stage. The Akah Stage represents the maximum detrital bioclastic/biogenic reservoirs. The source rocks for
Traps: Combination stratigraphic and structural trapping mechanisms
extent of evaporite limits. the Ismay stage are the Gothic, Hovenweep, and Boundary
are dominant among Pennsylvanian fields of the San Juan Basin and
Reservoirs: Almost all hydrocarbon production has been from vuggy The Desert Creek Stage carbonates were deposited in a definable Butte Shales. During the Ismay Stage the southern part of the
Four Corners Platform. Most fields are located on structures, although
limestone and dolomite reservoirs in five zones of the Hermosa Group. arcuate trend around the southeast terminus of the basin. The Desert basin was slowly subsiding.
not all of these structures demonstrate closure. The structures o o o
In ascending order they are the Alkali Gulch, Barker Creek, Akah, themselves may have been a critical factor in the deposition of 109 108 30' 108 EXPLANATION
Desert Creek, and Ismay Stages (Fig. UM-13). The zones gradually bioclastic limestone reservoir rocks. Seals are provided by a variety of
become less distinct toward the central part of the San Juan Basin. Net mechanisms, including porosity differences in the reservoir rock,
pay thicknesses generally range from 10 to 50 feet and have porosities Ute Mt. Ute Indian
overlying evaporites, and interbedded shales. Most production on the Reservation
of 5-20 percent. Four Corners Platform is from depths of 5,100 to 8,500 feet, but minor
Southern and eastern limit of halite
Source rocks: Source beds for Pennsylvanian oil and gas are believed production and shows in the central part of the San Juan Basin are from o
to be organic-rich shales and laterally equivalent carbonate rocks within as deep as 11,000 feet.
37 30' + ++ + Isopach Contour
the Paradox Formation. The presence of hydrogen sulfide (H2S) and Exploration status and resource potential: Field sizes in the play
200 Line of the Surface
+ 0
1600
+ of the Paradox Fm.
appreciable amounts of CO2 at the Barker Creek and Ute Dome fields
120
vary considerably; most oil discoveries are in the 1–100 MMBO size +
+ + Contour interval is
probably indicates high-temperature decomposition of carbonates, range and include associated gas production. The largest fields, Tocito
0
+ 100 ft
(Rice, 1983). Correlation of black dolomitic shale and mudstone units Cortez
18
Dome and Tocito Dome North, have produced a total of about 13
00 +
00
of the Paradox Formation with prodelta facies in clastic cycles present Location of drill
in a proposed fan delta complex on the northeastern edge of the
MMBO and 26 BCFG. Eight significant nonassociated and associated
1400 16 +
+ Durango holes used for
gas fields have been developed in the play, the largest of which, Barker + +
interpretation
Paradox Evaporite Basin helps to account for the high percentage of +
100 +
Creek, has produced 205 BCFG. The Pennsylvanian is 0 + +
110
o
108o EXPLANATION basically a gas play and has a moderate future potential
+
+
+
+
Paradox Basin for medium-size fields. UT +
CO
Province +
+
+
AZ ++ + + ++ + + NM
Characteristics of Play + + + + +
San Juan Basin + + + + + +
+ +
Province In the Ute Mountain Ute Indian Reservation the Para 800 +
++ Southern and eastern limit
dox Formation is conformably bounded by the Pinker + +
Ute Mt. Ute. Indian + + + + + of anhydrite
38o 38 o Reservation
ton Trail Formation at its base and the Honaker Trail ++ +
+
Formation at its top (Fig. UM-14). It ranges from 800 + ++
+ ++
Play Boundary +
feet thick in the south to 1700 feet thick in the north + + + +
600 +
+
Farmington N
(Fig. UM-14). The Paradox Formation was deposited +
+ +
during the Desmoinesian age of the Pennsylvanian Pe
A
+
A
Location riod under strong cyclic conditions involving transgres +
+
UT + + +
CO of Cross o
36 30'
+
+
sive and regressive movements of the Pennsylvanian
Section +
+ + +++ + +
A'
sea. The transgressive phase is represented by black or + + +
NM + + + +
AZ +
+
++
+ +
ganic rich dolomitic muds while the regressive phase is
+ + +
represented by carbonate mounds. Reservoirs within
+
400 +
the reservation are biogenic/bioclastic carbonate SCALE
A'
mounds deposited in shoaling areas of an evaporite ba +
800
++
SCALE sin. The four main cycles of Desmoinesian deposition + +
+ 0 25 miles
+ +
0 25 50 miles Figure UM-11. Location of Porous Carbonate Buildup
o
110 108o Play (modified after Peterson, 1996). Figure UM-12. Isopach map of the Paradox Formation (modified after Huffman and Condon, 1993).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY: Porous Carbonate Buildup 7
COLORADO AND NEW MEXICO
Analog Fields
HONAKER TRAIL FORMATION Within or Near Reservation
(*) denotes field lies within the reservation boundaries R-14-W R-13-W BARKER CREEK
PARADOX FIELD
UNCOMPAHGRE CUTLER ARKOSE
Boundary Butte
ISMAY *Barker Creek Paradox Field (Fig. UM-15)
STAGE Hovenweep Shale Location of discovery well: SE¼, SE¼, NW¼, Sec 21, T32N, R14W, 36 31
Gothic Shale NMPM (March, 1945)
DESERT CREEK
PARADOX FORMATION
STAGE Producing formation: Paradox Formation STRUCTURE MAP
HERMOSA GROUP
Chimney Rock
'
DATUM: TOP DESERT CREEK
0
Number of producing wells: 5 (1977) 1 4 1
-220
Production: 215,279,080 MCFG (1996)
AKAH PARADOX 141,773 BO (1977) SAN JUAN CO., N.M.
STAGE Gas characteristics: BTU 777 (dry basis) LA PLATA CO., COLO.
-2000'
Type of drive: Solution gas, fluid expansion, ineffective 6
bottom water encroachment
Average net pay: ± 100 feet T
Porosity: 2-10% 32 SP RES
EVAPORITES Permeability: extremely variable N
7800
0'
BARKER
20
CREEK Heron North Field
-2
21 7
ISMAY
1st
SWEET ZONES
LA PLATA CO., COLO.
STAGE Location of discovery well: NE ¼, NW ¼, sec. 35, T41N, R25W
7 SAN JUAN CO., N.M. 12
(1991)
2nd
Producing formation: Desert Creek Stage, Paradox Formation A
'
00
Number of producing wells: 1 6
P A R A D O X
ALKALI GULCH
'
8000
-18
0
80
Production: 0.31 BCFG
DESERT
CREEK
'
00
-1
Figure UM-13. Stratigraphic chart of the Pennsylvanian Hermosa Group illustrating the 200,759 BO (January 1, 1996) 11
0'
3rd
-20
00
Paradox facies change across the basin. Each stage is bounded by a time stratigraphic Average net pay: 60 feet
-2
marker bed of sapropelic, dolomitic mud. These markers are continuous and mappable Porosity: 15%
throughout the basin (modified from Harr, 1996). Permeability: 17.7 md
17 T
AKAH
A
8200
' 32
*Wickiup Field
A' 800
'
A'
00
DeChelly Sandstone (Upper) N
Location of discovery well: SW ¼, SE ¼, Sec 24, T33N, R14W
-1
-20
DeChelly Sandstone (Lower)
(March, 1972)
Producing formation: Barker Creek Stage, Paradox Formation 31 36 31
R-14-W
BARKER CREEK
Number of producing wells: 1 (1983)
SOUR
Organ Rock Formation Production: 41,872 MCFG (1996)
E.P.N.G.
8400
E.P.N.G. SO. UNION 1st
Gas characteristics: BTU 914. No. 6 Ute
No. 11 Ute No. 17 Barker
Type of drive: Gas Expansion
Cedar Mesa
Average net pay: 10 feet
1600' A A'
Sandstone 2nd
Halgaito Porosity: 8% G-W t CONTOUR
(-1840') 1s
Formation 2n
d DATUM
ZONES
DATUM rd
Rico Formation *Ute Dome Paradox Field 3
G-W
Location of discovery well: NE ¼, NE ¼, Sec 35, T32N, R14W
8600
Honaker Trail 2000' (-2000')
(September, 1948)
i
Ph
3rd
Formation
Producing formation: Barker Creek Stage, Paradox Formation
t
dc
Number of producing wells: 11 (1977) 1s
Paradox Formation
Ph
Production: 93,589,058 MCFG (1996) 2n
d G-W
(-2300')
a
Gas characteristics: BTU 777 (dry basis)
Ph
PARADOX
Type of drive: Primary Volumetric with limited water G-W
3rd (-2430')
Molas Formation drive in Barker Creek Zone
bc
1000 2500'
Ph
Feet Average net pay: 116 feet
ks
ozoic roc
G-W
ag
wer Pale
(-2630')
Ph
Porosity: 3.5%
Pinkerton Trail p ian and lo
Mississip
Permeability: 0.5 md (enhanced by fracturing)
Figure UM-15. Structure contour map, type log, and cross section of Barker Creek Paradox Field (modified
Formation 0
0 10 Miles
from Matheny, 1978).
Figure UM-14. Stratigraphic cross section through Ute Mountain Ute Indian Reservation
(modified from Huffman and Condon, 1993).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY: Porous Carbonate Buildup 8
COLORADO, NEW MEXICO
Tocito-Gallup Sandstone Oil Play R14W
(USGS Designation 2207) 110 o 108o EXPLANATION
Figure UM-17. Location of
Paradox Basin oil field discovery wells for
General Characteristics Province fields producing from the
The Tocito-Gallup Sandstone Oil Play is an oil and associated gas T Tocito-Gallup Sandstone Oil
Ramora 33
play in lenticular sandstone bodies of the Upper Cretaceous Gallup San Juan Basin N Play.
Province Chipeta
Sandstone and Tocito Sandstone Lentil, associated with Mancos Aztec T
32
Shale source rocks lying immediately above an unconformity. The Ute Mt. Ute. Indian Wash N
UT CO
38o 38 o Reservation
play covers almost the entire area of the province (Fig. UM-16). AZ NM R19W Many Rocks T
32
Gallup North Many Rocks
Most of the producing fields are stratigraphic traps along a north Play Boundary Mesa N
Gallup Gallup
west- trending belt near the southern margin of the central part of the T
31
San Juan Basin. Almost all production has been from the Tocito N
Sandstone Lentil of the Mancos Shale and the Torrivio Member of
A
Horseshoe R14W
the Gallup Sandstone. Locations of oil field discovery wells produc A' Shiprock Gallup
UT CO Location North Gallup
ing from the Tocito-Gallup Sandstone Oil Play are shown in figure
AZ NM of Cross Jewet
UM-17. Rattlesnake Waterflow
A'
Section Group Shiprock Valley Gallup
Reservoirs: The Tocito Sandstone Lentil of the Mancos Shale is the Gallup Gallup South Totah
major oil producing reservoir in the San Juan Basin. The name is ap Gallup
plied to a number of lenticular sandstone bodies, commonly less than EXPLANATION
50 feet thick, that lie on or just above an unconformity and are of un Cha Cha
Approximate location of discovery Gallup
determined origin. Reservoir porosities in producing fields range SCALE well for named oil field
from 4 to 20 percent and average about 15 percent. Permeabilities Limits of Ute Mountain Ute Indian N
Reservation
range from 0.5 to 150 Md and are typically 5 - 100 Md. The only 0 25 50 miles
SCALE
significant production from the regressive Gallup Sandstone is from 110 o A 108o 0 10 miles
the Torrivio Member, a lenticular fluvial channel sandstone lying Figure UM-16. Location of the Tocito-Gallup Oil Play. Cross section A- SAN JUAN BASIN
above, and in some places scouring into the top of the main marine A' is shown in Figure UM-18 (modified after Gautier, et al.,1996) A SOUTH STRATIGRAPHIC CROSS SECTION NORTH A'
Gallup Sandstone.
KIRTLAND SHALE FM MAESTRICHTIAN
Source rocks: Source beds for Gallup oil are found in the marine acres and has estimated total ultimate recovery of 51 MMBO. FRUITLAND FM
SECTION REMOVED BY LATE PICTURED CLIFFS SS
Upper Cretaceous Mancos Shale. The Mancos contains 1-3 weight Gallup producing fields are typically 1,000-10,000 acres in area and TERTIARY TO QUARTERNARY EROSION
percent organic carbon and produces a sweet, low-sulfur, paraffin- have 15-30 feet of pay. About one-third of these fields have an
base oil that ranges from 38° to 43° API gravity in the Tocito fields estimated cumulative production exceeding 1 MMBO and 1 BCF of CLIFF HOUSE SS
LEWIS
SHALE CAMPANIAN
and from 24°to 32° API gravity farther to the south in the Hospah associated gas. All of the larger fields produce from the Tocito
UPPER CRETACEOUS
and Hospah South fields. Sandstone Lentil of the Mancos Shale and are stratigraphically
MESAVERDE
Timing and migration: The Upper Mancos Shale of the central part controlled. South of the zone of sandstone buildups of the Tocito, GROUP MENEFEE FM
POINT LOOKOUT SS
of the San Juan Basin entered the thermal zone of oil generation in the regressive Gallup Sandstone produces primarily from the fluvial
the late Eocene and gas generation in the Oligocene. Migration up channel sandstone of the Torrivio Member. The only large fields
dip to reservoirs in the Tocito Sandstone Lentil and regressive Gallup producing from the Torrivio are the Hospah and Hospah South CREVASSE UPPER MANCOS SHALE SANTONIAN
CANYON FM
followed pathways similar to those determined by present structure fields, which are combination traps. Similar, undiscovered traps of
BORREGO PASS SS
because basin configuration has changed little since that time. small size may be present in the southern half of the basin. The
DILCO MEMBER CONIACIAN
future potential for oil and gas is low to moderate. MEMBER A TOCITO SANDSTONE
Traps: Almost all Gallup production is from stratigraphic traps at TORRIVIO B
depths between 1,500 and 5,500 feet. Hospah and Hospah South, the GALLUP
SANDSTONE C
TURONIAN
largest fields in the regressive Gallup Sandstone, are combination JUANA LOPEZ MBR.
LOWER MANCOS
D SHALE
stratigraphic and structural traps. The Tocito Sandstone is sealed by, GREENHORN LS MBR
E
encased in, and intertongues with the marine Mancos Shale, forming CENOMANIAN
F
stratigraphic traps. Similarly, the fluvial channel Torrivio Member DAKOTA SANDSTONE
of the Gallup is encased in and intertongues with finer grained, or
ganic-rich coastal-plain shales. Figure UM-18. Schematic south to north cross-section non-marine ss/sh estuarine ss (reservoir)
Exploration status and resource potential: Initial Gallup field of the Cretaceous stratigraphy in northwestern New shoreface sandstone muddy estuarine ss (largely non-reservoir)
discoveries were made in the mid 1920's, however the major Mexico with emphasis and detail on the late Turonian-
open marine shale estuarine open marine shale
Coniacian interval (modified after Molenaar, 1973,
discoveries were not made until the late 1950's and early 1960's in
1983a,b). marine limestone braided-fluvial sandstone
the deeper Tocito fields. The largest of these, Bisti, covers 37,500
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY TYPE: Tocito- Gallup Sandstone Oil Play 9
COLORADO, NEW MEXICO
Characteristics of the Tocito-Gallup Oil Play
BEAUTIFUL MOUNTAIN
SUBSURFACE 331/2N 331/2N
In recent years a sequence stratigraphic framework has been applied OUTCROP 15W 13W
331/2N
to the Tocito and Gallup Sandstones near the Ute Mountain Ute In 19W
0
TST
dian Reservation (Jennett and Jones, 1995). This framework ex LST
plains hydrocarbon occurrence and the stratigraphic traps associated TOCITO 0 UTE MOUNTAIN UTE 33N
TOCITO-4 SB 30
with these units. The northern extent of the Gallup Sandstone pro INDIAN RESERVATION 13W
Torrivio
duction is several miles south of the Indian reservation where it is 0
truncated by the Tocito Sandstone (Fig. UM-18). For this reason the
Nonmarine LST
0
lithofacies TOCITO-3 SB 10
Gallup Sandstone will not be included in the following description. HST
32N 0 32N
Since the late 1950 ’s, 130 MMBOE have been produced from
19W COLORADO 13W
TST
the Tocito. The Tocito Sandstone marks a significant change from NEW MEXICO 32N
LST TOCITO-2 SB 32N 13W
shoreface/coastal plain depositional systems which prevailed MANY ROCKS VALLEY
19W 10
throughout Gallup deposition. The Tocito Sandstone is a transgres GALLUP TST/HST
sive sequence set internally composed of four high- frequency se HORSESHOE VALLEY
TOCITO-1 SB DOWNDIP LIMIT OF
quences; in ascending order they are Tocito-1, Tocito-2, Tocito-3 and LST
Shallow 31N RESERVOIR QUALITY SS
Tocito-4 (Fig. UM-19). In the subsurface, the Tocito is distributed
marine JUANA LOPEZ MBR.
18W
into narrow and elongate bodies which trend northwest-southeast 0
(Figs. UM-20 to UM-23). (T
RU LIM 10 IN
The high-frequency sequences of the Tocito Sandstone contain NC IT 0 TERF 0
RATTLESNAKE AT OF
the lowstand, transgressive, and usually highstand systems tracts. ED TO
LU
VE
There are sequence boundaries at the base of each high-frequency se BY TCI 0
quence represented by irregular erosional surfaces that truncate into open marine shale TO O 1
CI SE
the underlying units. Above the erosional surfaces are incised valley JUANA LOPEZ MBR. shallow marine sandstone TO Q
2 S UE
EQ NC
29N
fill deposits representing the lowstand systems tracts. The tops of the fluvial/distributary/bay fill sandstone
valley fills represent transgressive flooding surfaces, the passage HOGBACK
16W
UE E B 0
carbonaceous shale NC OU
from valley-filling sedimentation to open-marine/shelfal sedimenta E ND
estuarine sandstone BO A
tion, and the onset to the transgressive systems tracts. The transgres HST = high stand systems tract UN RY 0
calcareous/fossiliferous sandstone 28N THE SHIPROCK DA 10
sive systems tracts are overlain by distal marine shales of the high TST = transgressive systems tract 19W RY 10
stand systems tracts (Tocito-1 and Tocito-2 only). Due to their close
LST = low stand systems tract
TOCITO 1 SEQUENCE )
vertical juxtaposition, the four Tocito sequences are collectively in Figure UM-19. Composite stratigraphic summary comparing the outcrop of the Gallup and Tocito INCISED VALLEY FILL ISOPACH
terpreted as components of a sequence set. The four sequences are interval. Along Beautiful Mountain, a relatively complete Gallup section from the Juana Lopez to the CONTOUR INTERVAL 10 FEET
Torrivio Sandstone occurs beneath the Tocito Sandstone Lentil. To the north in the subsurface, four 0 2 4 6
thought to reflect higher-order cycles in relative sea level which were ROCK RIDGE
sequences compromise the Tocito interval, with the lowermost sequence boundary erosionally resting MILES
superimposed on a longer term cycle.
on beds of the Juana Lopez Member. The missing section is close to 400 feet. The sequence LEGEND
Hydrocarbon trapping is the result of stratigraphic relationships. boundaries merge toward the outcrop and form a composite surface which everywhere separates Tocito OUTCROP MEASURED SECTION
Structural dip is uniformly toward the northeast and consequently strata from the underlying Gallup strata (modified after Jennette and Jones 1995). 26N
INCISED VALLEY FILL
provides only minor influence on the pooling of hydrocarbons. The 14W
four main trapping elements are truncation by younger sequence PALEOCURRENT DIRECTION
boundaries, arcuate bends in valleys, up-dip valley termination, and
structural closure (Fig. UM-24). Figure UM-20. Isopach map of the Tocito-1 incised valley system. Two parallel valleys, the Horseshoe
and Many Rocks valleys, are separated by a well defined interfluve. Note the position and paleocurrent
patterns of the Mounds outcrop locality. Reservoir quality sandstone appears to be present farther
down the Horseshoe valley (modified after Jennette and Jones, 1995).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY: Tocito-Gallup Sandstone Oil Play 10
COLORADO AND NEW MEXICO
331/2N 331/2N 331/2N 331/2N 331/2N 331/2N 331/2N 331/2N 331/2N 331/2N 331/2N
331/2N
20W 15W 13W 9W 20W 15W 13W 9W 20W 15W 13W 9W
UTE MOUNTAIN UTE
UTE MOUNTAIN UTE INDIAN RESERVATION
UTE MOUNTAIN UTE 33N 33N 33N 33N
30
30 33N
33N 33N
20W INDIAN RESERVATION 13W 9W 20W 40 9W
INDIAN RESERVATION
20W 9W
10 VERDE VALLEY 40
20
0 0 32N 32N
40
32N 32N
32N 0 32N 32N 30 COLORADO
32N
COLORADO
20W 0 13W COLORADO 9W
20W 9W 20W 13W 9W
32N TO 32N NEW MEXICO 32N
32N 20 VERDE VALLEY 20 NEW MEXICO 32N 32N NEW MEXICO 32N
IN
TE C 13W
20W 20W 30 13W 10W
20W
RF ITO 10W
30 40
LU BY 2 T
VE TO RUN 20 40
0 CIT C 10
0 O 3 ATE 31N
TO D 31N
THI 31N
10
C 20W N NED
BY TOCITO 10W 20W 20
10
10
IT 4 TR
UN 30
O 0 C ATION
2
TR
U IN 10
N 0 TE
C RF 30N 30N 40
30N A 0 LUV 20W RATTLESNAKE 30N RATTLESNAKE
RATTLESNAKE TED
20W
20W
0 IN 5
TE 0 E 13W
10 60 0 TOCITO 4 SEQUENCE
B 20 R
Y FL
TO UV 20 INCISED VALLEY FILL ISOPACH
C 30 20
IT E 29N 29N 0 2 4 6
O 30 29N 15W 10W
3 10W HOGBACK HOGBACK W MILES
HOGBACK TO 20 10 AT
VALLEY C ITO E RF OUTCROP MEASURED
0 3
TH RA 20 LO SECTION
20 10 28N THE SHIPROCK IN
N 28N THE SHIPROCK TT W
28N THE SHIPROCK IN CHA CHA VALLEY 20W ED 50 WATERFLOW VALLEY 20W LE VA INCISED VALLEY FILL
20W TE
RF
BY
S LLE
L UV
TO
CIT 20 NA Y 50
O4
TR
70 30 20 0 KE 20
E UN
10 CAT
ION
VA
WATERFLOW VALLEY ROCK RIDGE L 40
ROCK RIDGE 0 10 TOC 10 ROCK RIDGE LE
0 TO
C
ITO
2 TRU Y
ITO NCA
TED 50 10 RO
2T BY T C 10 IN 0 20
RU OCIT
26N 20 50 K TE
N CA
O3
26N RI RF
26N
TE
17W
30 17W DG
17W
10 DB EV LU
BEAUTIFUL MOUNTAIN VE
BEAUTIFUL MOUNTAIN 0 Y TOC BEAUTIFUL MOUNTAIN AL
ITO BISTI VALLEY LE
BIS
TI V 3 TOCITO 3 SEQUENCE 10 50 Y
TOCITO 2 SEQUENCE A LLE
INCISED VALLEY FILL ISOPACH
INCISED VALLEY FILL ISOPACH Y 0 2 4 6 10 10
INT MILES
CONTOUR INTERVAL 10 FEET TOC ER
FL
0 2 4 6 I TO UV
E LEGEND 0 10
2 TRU 0 10 ?
MILES NCA OUTCROP MEASURED SECTION 24N 24N
24N TED 13W
0
13W
LEGEND 13W BY T
OCI INCISED VALLEY FILL
OUTCROP MEASURED SECTION TO
3
PARTIALLY TRUNCATED BY
INCISED VALLEY FILL
23N OVERLYING SEQUENCE
23N 23N ? 23N
23N 23N 10W 17W 10W
18W
17W 10W
Figure UM-23. Isopach map of the Tocito-4 incised
Figure UM-21. Isopach map of the incised valley fill of Figure UM-22. Isopach map of the Tocito-3 sequence.
valley-fill sequence. Valley fills make up the bulk of the
the Tocito-2 sequence. Four parallel valleys, each sepa The interval mapped is from the Tocito-3 sequence
map and are separated by narrow interfluvial areas.
rated by interfluves, are evident. The Waterflow Valley boundary to the Tocito-4 sequence boundary. A wider
The isopach patterns mapped in the subsurface cor
contains the thickest interval of sandstone. Note the over array of valley shapes is evident: the broad Verde Val
respond remarkably well with measured thickness of
all distribution of the lowstand systems tract is more ley, the deep, V-shaped Waterflow Valley, and the asym
the Tocito at the outcrop (C.V. Campbell, unpublished
widespread than the Tocito-1 sequence. The Tocito-3 se metric Bisti Valley. Note the areas thinned by truncation
Exxon Production Research data). Most of the Tocito
quence boundary incises and removes the Tocito-2 se by the overlying Tocito-4 sequence boundary, particular
in outcrop along Rock Ridge and Beautiful Mountain
quence along the southern margin of the Waterflow Val ly along the southern margin of the Waterflow Valley and
belongs to the Tocito-4 sequence (modified after Jen
ley and northern margin of the Bisti Valley. These narrow toward the outcrop area (modified after Jennette and
nette and Jones, 1995).
bands of truncation correspond to axial thicks in the Toci Jones, 1995).
to-3 sequence. This erosional relationship has led to a
number of hydrocarbon traps in this vicinity (modified af
ter Jennette and Jones, 1995).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY: Tocito-Gallup Sandstone Oil Play 11
COLORADO, NEW MEXICO
Analog Fields Near the Reservation INCISED VALLEY TRAPPING MECHANISM R16W
1. VALLEY CHANGES DIRECTION MANY ROCKS GALLUP NORTH
Many Rocks Gallup
10
'
(Figs. UM-25 - UM-27) MESA
Location of discovery well: SE ¼, SW ¼, sec 27, T32N, R17W
T GALLUP 10 0'
0'
'
15
(1962)
'
32 0'
Producing formation: Cretaceous Gallup Sandstone N
Number of producing wells: 62 (1977)
Horseshoe Field 40 MOEB
U
Production: 9 MOEB (1995) Cha Cha Field 14 MOEB D
1,047,270 MCFG (1977) Many Rocks Field 9 MOEB
Gas Characteristics: 1,171 BTU Totah Field 6 MOEB
Oil Characteristics: 40 ° API gravity
30
5' MANY ROCKS
' 10
2. VALLEY TRUNCATED BY YOUNGER SEQUENCE BOUNDARY ' GALLUP
Type of drive: Solution gas with limited gas expansion
T 20
Average net pay: Upper zone is 5 feet 31 HORSESHOE ' 30
'
5'
Lower zone is 7.5 feet N GALLUP
Porosity: 15%
0'
Permeability: 145 mD
R18W
Bisti Field 54 MOEB MANY ROCKS
Horseshoe Gallup Figure UM-24. Gallagos Field 10 MOEB
HORSESHOE GALLUP AREA
0'
Schematic summary
40
'
Location of discovery well: NW ¼, SW ¼, sec 8, T32N, R17W of hydrocarbon SAN JUAN CO., N.M.
(1961) trapping styles found 3. VALLEY TERMINATION ISOPACH MAP
0'
20
'
Producing formation: Cretaceous Tocito Sandstone in the Tocito, stippled UPPER PAY SAND
Number of producing wells: 9 (1983) patterns indicate the ISOPACH INTERVAL 5', 10'
position of oil R17W R16W
Production: 40 MOEB (1995)
accumulations
Oil characteristics: 35 ° API gravity (modified after Figure UM-26. Isopach map of the “lower sand pay zone” for the Many Rocks Field (modified after
Type of drive: water Jennette and Jones, Matheny and Little, 1978).
Average net pay: 15 feet 1995). TOCITO-3 SEQUENCE ABOVE
Horseshoe Field
Porosity: 10 -15 %
Permeability: unknown MANY ROCKS GALLUP FIELD
Stratigraphic Cross Section
R16W
Cha Cha Gallup CURTIS - LITTLE SKELLY
MANY ROCKS GALLUP NORTH CURTIS - LITTLE CURTIS - LITTLE CURTIS - LITTLE CURTIS - LITTLE
SE 28-32N-17W SE 27-32N-17W SE 27-32N-17W SE 27-32N-17W SE 27-32N-17W SW 26-32N-17W
Location of discovery well: NW ¼, SE ¼, sec 17, T28N, R13W MESA
Producing formation: Cretaceous Gallup Sandstone T GALLUP
1100
1100
Number of producing wells: 42 (1977) 32
N
1600
Production: 14 MOEB (1995)
17,965,301 MCFG (1977)
Oil characteristics: 41 ° API gravity
1700
Type of drive: Solution Gas
1700
MANY ROCKS
1200
Average net play: Upper zone 10 feet
1200
GALLUP
Lower zone 10 feet T
A A'
17 00
31 HORSESHOE
Porosity: 13.5% N GALLUP 5'
Permeability: 57 mD GR IND.
0'
SB JUANA
5'
R18W GR IND. GR IND. GR IND.
GR IND.
LST LOPEZ GR IND.
0'
LOWER PAY SAND
Many Rocks Horseshoe
Gallup Area
SAN JUAN COUNTY, NM
5'
10'
Figure UM-25. Isopach map of the “upper Figure UM-27. Stratigraphic cross section of the “lower sand pay zone” for the Many Rocks Field.
ISOPACH MAP
sand pay zone” for the Many Rocks Field Hydrocarbons are trapped in the Tocito- 1 lowstand systems tract (Fig. UM-19) along updip bends in the
UPPER PAY SAND
15
(modified after Matheny and Little, 1978). valley (modified after Jennette and Jones, 1995; Matheny and Little, 1978).
'
ISOPACH INTERVAL 5' R17W
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY: Tocito-Gallup Sandstone Oil Play 12
COLORADO, NEW MEXICO
MANCOS FRACTURED SHALE PLAY developed parallel to the trend of the fold. They range in size from Figure UM-28. Location of 110 o 108o EXPLANATION
(USGS Designation 2208) hairline cracks to 1 ¾ inches wide. Mancos Fractured Shale Play
Oil reservoirs associated with the Mancos Fractured Shale Play (modified after Peterson, Paradox Basin
General Characteristics depend on porosity and permeability provided by the fractures. The 1996) Cross section A-A' is Province
The Mancos Fractured Shale Play is a confirmed, unconventional, con shown in Figure UM-30.
reservoirs are lithologically controlled only to the extent that brittle San Juan Basin
tinuous-type play. It is dependent on extensive fracturing in the organ competent interbeds capable of fracturing are present. The fractures Province
ic- rich marine Mancos Shale. Most developed fields in the play are have greater lateral than vertical continuity. The basic tools used in
Ute Mt. Ute. Indian
associated with anticlinal and monoclinal structures around the eastern, exploration for fracture permeability are structure contour maps and 38o 38 o Reservation
northern, and western margins of the San Juan Basin (Figs. UM-28 and lithofacies maps showing brittle interbeds in dominantly shaly sequen
UM-29). Play Boundary
ces.
Trap types are structural/stratigraphic-fracture traps. The reser
Reservoirs: Reservoirs are comprised of fractured shale and interbed voirs are primarily driven by gravity drainage.
ded coarser clastic intervals at approximately the Tocito Lentil strati
UT CO
graphic level.
AZ A' NM Location
Source rocks: The Mancos Shale contains 1-3 weight percent organic
A
of Cross
carbon and produces a sweet, low-sulfur, paraffin-base oil that ranges Section
from 33° to 43° API gravity.
A'
Timing: The Upper Mancos Shale of the central part of the San Juan
R18W R17W A
Basin entered the thermal zone of oil generation in the late Eocene and 6000
SCALE
of gas generation in the Oligocene.
Traps: Combination traps predominate. Traps are formed by fractur 0 25 50 miles
5000
ing of shale and by interbedded coarser clastics on structures. 110 o 108o
Exploration status and resource potential: Most of the larger dis
coveries, such as Verde and Puerto Chiquito, were made prior to 1970, 4000
SW NE
but directional drilling along the flanks of some of the poorly explored
A A'
Hogback Monocline
structures could result in renewed interest in this play. T
k
42 T
e e
lin re
S 33
oc s C
3000 N
Dalton Ss.
on o
T
M anc
Characteristics of Mancos Fractured Shale Play in 41
S Upper Mancos Shale
M
T
the Ute Mountain Ute Indian Reservation UT CO 32
N
T he Mancos Fractured Shale Play produces oil from fractures in AZ NM MANCOS RIVER Borrego Pass lentil "Skelly zone"
the Niobrara-Carlile age clastic sediments (Fig. UM-30) which repre T (Stray Ss)
41 Tocito Ss. lentil
sent the first regressive wedge in the San Juan Basin. These sediments S
Dilco
have little or no effective porosity and permeability except that associ LAPLATA
VERDE
T GALLUP
ated with fractures. The units of interest to oil exploration are the basal 40 Bisti field
S
Niobrara (lower Tocito Sandstone), Niobrara-Carlile unconformity
Gallup Gallegos field
(upper Carlile Shale-Tocito Sandstone contact), and Carlile Shale/silt
stone contact interval above the Juana Lopez. The Niobrara-Carlile
stage is laterally consistent with respect to siltstone content, cement
content, and other observable stratigraphic phenomenon. EXPLANATION
The Hogback Monocline and Mancos Creek Monocline (Fig. UM- SCALE
Approximate location of discovery well 200ft
29) are the structural features associated with fractures in the Mancos for named oil field
0 10 miles
Shale. The Hogback Monocline is located in the northwest flank of the
San Juan Basin in the southeast section of the Ute Mountain Ute Indian
Limits of Ute Mountain Ute Indian Reservation N
0
Reservation. It has a dip as great as 60° and has up to 8000 feet of Structure contour line drawn on base of Dakota Sandstone. 0 10mi
structural relief. The Mancos Creek Monocline is located south of the
reservation and extends only a few miles. Fractures are mostly associ C. I. = 600 feet
Figure UM-29. Structure contour map of the basal Dakota Sandstone showing the Hogback Monocline, Figure UM-30. Subsurface stratigraphic cross section across the central San Juan Basin. Dashed
ated with areas of maximum flexure and where anticlines and synclines lines are time marker bentonites or calcareous silty zones (modified from Molenaar, 1973; Tillman,
intersect the monoclines (Figs. UM-31 and 32). The fractures are best associated folds, and location of oil field discovery wells for fields producing from the Mancos Fractured
Shale Play (modified after Anderson, 1995). 1985).
UTE MOUNTAIN UTE RESERVATION UNCONVENTIONAL PLAY TYPE: Mancos Fractured Shale Play 13
COLORADO, NEW MEXICO
Analog Fields inside or near Reservation
(*) denotes field lies within the reservation boundaries
*Verde Oil Field (Fig. UM-31)
LA PLATA GALLUP FIELD
Location of discovery well: se ¼,sec. 14, T31 N, R15W, NMPM BENSON- MONTIN-GREER DRLG. CORP.
(September 1955) STRUCTURAL CONTOUR MAP
La Plata Mancos No. P-31
Producing formation: Fractured interval in Niobrara age Mancos Shale
se 31 - T32N - R13W
Number of producing wells: 27 (1978) CONTOURED ON ELECTRIC GAMMA RAY - INDUCTION
Production: 7,789,304 bbl. (1977) LOG MARKER "E" WITHIN
Oil characteristics: 38 ° - 42° API Gravity Elev - R.K.B. 6075
MANCOS SHALE
Type of drive: Gravity drainage in entire field as a “unit”
CONTOUR INTERVALS: 19 22
La Plata Gallup Field (Fig. UM-32)
Location of discovery well: se ¼, sw ¼, sec 5, T31N, R13W, NMPM 1000'
A
(April 1959) 100' T
Producing formation: Fractured Mancos Shale. 32
Number of producing wells: 4 (1978) BOUNDARY OF LA PLATA N
GALLUP POOL
Production: 527,882 bbl. (1977) B
Oil characteristics: Sweet yellow-green, 30 ° API Gravity. 30 27
Producing Dakota and Pennsylvanian
Type of drive: Combination gravity and solution gas wells within mapped area are not shown.
Mancos River Field
Location of discovery well: E ½ Sec 15, T32N, R18W, NMPM
Producing formation: Fractured Mancos Shale. C
UTE MOUNTAIN TRIBAL INDIAN RESERVATION
Number of producing wells: 2 (1978)
Production: 22,750 bbl. (1982) 35 36 33 34
31
Oil characteristics: 40 ° API Gravity
P-31
0
20
+4
5400 2 1
3
0
00
400
VERDE
+2
5
0
520 0 T D
FIELD 500 31
T
800 N
0
4 31
00
0
00
00
+4
0
0 1
00
440 N +4
+1
8 10
-0-
+3
4000
NE
E
I
CL
3600
-200
NO
-100
Gamma Induction
O
M R13W
AC
K 0 R14W Ray
GB 240
HO
00
22
Figure UM-32. Structure contour map and type log of the La Plata Gallup field. Structure contour lines are on the “E” marker within the Mancos Shale (top of
the Niobrara Stage) which generally produces the highest electrical log resistivities in the Mancos Shale (modified after Greer, 1978).
00
T
20
00
30
30
CI - 200ft N
R15W 0 1 2 3 4 miles
R14W
Figure UM-31. Generalized structure contour map of Verde field. Structure contours are on top of the Point
Lookout Sandstone Member of the Mesaverde Group (modified from Hayes and Zapp, 1955).
UTE MOUNTAIN UTE RESERVATION UNCONVENTIONAL PLAY TYPE: Mancos Fractured Shale 14
COLORADO, NEW MEXICO
Central Basin Mesaverde Gas Play ner grained paludal or marine sediments account for almost all of the A SAN JUAN BASIN
(USGS Designation 2209) stratigraphic traps with a shale or coal seal. SOUTH STRATIGRAPHIC CROSS SECTION NORTH A'
Exploration Status and Resource Potential: The Blanco Mesaverde MAESTRICHTIAN
KIRTLAND SHALE FM
General Characteristics
field discovery well was completed in 1927, and the Ignacio Blanco FRUITLAND FM
The unconventional continuous-type Central Basin Mesaverde Mesaverde field discovery well was completed in 1952. Areally, these
SECTION REMOVED BY LATE PICTURED CLIFFS SS
TERTIARY TO QUATERNARY EROSION
Gas Play is in sandstone buildups associated with stratigraphic ris two closely adjacent fields cover more than 1,000,000 acres, encom
es in the Upper Cretaceous Point Lookout and Cliff House Sand pass much of the central part of the San Juan Basin, and have produced LEWIS
stones in the central San Juan Basin (Fig. UM-33). The major almost 7,000 BCFG and more than 30 MMB of condensate, approxi
CLIFF HOUSE SS SHALE CAMPANIAN
gas-producing interval in the San Juan Basin, the Upper Creta mately half of their estimated total recovery. Most of the recent gas
UPPER CRETACEOUS
ceous Mesaverde Group, is composed of the regressive marine discoveries range in areal size from 2,000 to 10,000 acres and have es MESAVERDE
MENEFEE FM
Point Lookout Sandstone, the nonmarine Menefee Formation, and timated total recoveries of 10 to 35 BCFG.
GROUP
POINT LOOKOUT SS
the transgressive marine Cliff House Sandstone. Total thickness
of the interval ranges from about 500 to 2,500 feet, of which 20-50
percent is sandstone. The Mesaverde interval is enclosed by ma Basin Margin Mesaverde Oil Play CREVASSE UPPER MANCOS SHALE SANTONIAN
rine shale: the Mancos Shale is beneath the interval and the Lewis (USGS Designation 2210)
CANYON FM
BORREGO PASS SS
Shale above (Fig. UM-34).
DILCO MEMBER CONIACIAN
General Characteristics MEMBER A TOCITO SANDSTONE
TORRIVIO
Reservoirs: Principal gas reservoirs productive in the Mesaverde The Basin Margin Mesaverde Oil Play is a confirmed oil play around B
GALLUP
interval are the Point Lookout and Cliff House marine sandstones. the margins of the central San Juan Basin (Fig. UM-35). Except for SANDSTONE C
JUANA LOPEZ MBR. TURONIAN
Smaller amounts of dry, nonassociated gas are produced from the Red Mesa field on the Four Corners Platform, field sizes are very D
LOWER MANCOS
SHALE
thin, lenticular channel sandstone reservoirs and thin coal beds of small. The play depends on intertonguing of porous marine sandstone
GREENHORN LS MBR
E
the Menefee. Much of this play is designated as tight, and reser at the base of the Upper Cretaceous Point Lookout Sandstone with the CENOMANIAN
voir quality depends mostly on the degree of fracturing. Together, organic-rich Upper Mancos Shale. F
DAKOTA SANDSTONE
the Blanco Mesaverde and Ignacio Blanco fields account for al
Reservoirs: Porous and permeable marine sandstone beds of the basal
most half of the total nonassociated gas and condensate production non-marine ss/sh estuarine ss (reservoir)
Point Lookout Sandstone provide the principal reservoirs. The thick
from the San Juan Basin. Within these two fields porosity averag
ness of this interval and of the beds themselves may be controlled to shoreface sandstone muddy estuarine ss
es about 10 percent and permeability less than 2 mD; total pay (largely non-reservoir)
some extent by underlying structures oriented in a northwesterly direc open marine shale estuarine open marine shale
thickness is 20-200 feet. Smaller Mesaverde fields have porosities
tion.
ranging from 14 to 28 percent and permeabilities from 2 to 400 marine limestone braided-fluvial sandstone
mD, with 6-25 feet of pay thickness. Source Rocks: The Upper Mancos Shale intertongues with the basal
Point Lookout Sandstone and has been positively correlated with oil Figure UM-34. Schematic south to north cross section of the Cretaceous stratigraphy in the northern San Juan Basin (modified after Molenaar,
Source Rocks: The carbon composition (C /C
13 1 1-5) of 0.99-0.79 produced from this interval (Ross, 1980). API gravity of Mesaverde
1973, 1983a,b).
and isotopic carbon (d C1) range of -33.4 to -46.7 per mil of the
oil ranges from 37° to 50°. o
EXPLANATION o
EXPLANATION
nonassociated gas suggest a mixture of source rocks including 110 108o 110 108o
coal and carbonaceous shale in the Menefee Formation (Rice, Timing: Around the margin of the San Juan Basin the Upper Mancos
Paradox Basin Paradox Basin
1983). Shale entered the thermal zone of oil generation during the Oligocene. Province Province
Timing and Migration: In the central part of the basin, the Man Traps: Structural or combination traps account for most of the oil pro San Juan Basin San Juan Basin
Province Province
cos Shale entered the thermal zone of oil generation in the Eocene duction from the Mesaverde. Seals are typically provided by marine
Ute Mt. Ute. Indian Ute Mt. Ute. Indian
and of gas generation in the Oligocene. The Menefee Formation shale, but paludal sediments or even coal of the Menefee Formation 38o 38 o Reservation 38o 38 o Reservation
also entered the gas generation zone in the Oligocene. Because may also act as the seal.
Play Boundary Play Boundary
basin configuration was similar to that of today, updip migration Exploration Status and Resource Potential: The first oil-producing
would have been toward the south. Migration was impeded by hy area in the state of New Mexico, the Seven Lakes Field, was discov
A
Location
A
Location
drodynamic pressures directed toward the central basin, as well as ered by accident in 1911 when a well being drilled for water produced UT
of Cross
of Cross
CO Section UT CO
A'
by the deposition of authigenic swelling clays due to de-watering oil from the Menefee Formation at a depth of approximately 350 feet.
A'
Section
A'
AZ
A'
NM AZ NM
of Menefee coals. The only significant Mesaverde oil field, Red Mesa, was discovered in
Traps: Trapping mechanisms for the largest fields in the central 1924.
part of the San Juan Basin are not well understood. In both the
Blanco Mesaverde and Ignacio Blanco fields, hydrodynamic
SCALE SCALE
forces are believed to contain gas in structurally lower parts of the
0 25 50 miles 0 25 50 miles
basin, but other factors such as cementation and swelling clays o
108o o
108o
110 110
may also play a role. Production depths are most commonly from
A
A
4,000 to 5,300 feet. Updip pinchouts of marine sandstone into fi Figure UM-33. Location of the Central Basin Mesaverde Gas Play Figure UM-35. Location of the Basin Margin Mesaverde Oil Play
(modified after Gautier, et al., 1996). (modified after Gautier, et al., 1996).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL / UNCONVENTIONAL PLAY: Basin Margin Mesaverde Oil Play / Central Basin Mesaverde Gas Play 15
COLORADO, NEW MEXICO
Basin Margin Mesaverde Oil Play
and Central Basin Mesaverde Gas Play
o
109o00' 108o00'
Lower
1HCMS
1
* 1
2HCMS
750
37 30' Cortez
Stratigraphy and Analog Fields coastal 2
Lower
The Cliff House and Point Lookout Sandstones are the producers of the Ba 160 plain 900
coastal
3
sin Margin and Central Basin Mesaverde Plays in the Ute Mountain Ute In Durango
800 plain
dian Reservation. Mesa Verde 4
Foreshore 2
N.P.
COLORADO
The Point Lookout Sandstone is the most extensive regressive marine 950 5
3
Cretaceous sandstone in the San Juan Basin. The unit progrades from south SOUTHERN UTE 6 850
west to northeast in a series of imbricated sandstone units (Fig. UM-36). 4
INDIAN RES. Upper 7 Shoreface/
The depositional environments present in the Cliff House Sandstone are flu 5 delta front
UTE MOUNTAIN UTE RESERVATION 1HCMS shoreface 1000 8
vial/estuarine, shoreface, and delta front. Reservoir characteristic studies 6
have shown that the upper shoreface and shoreface/delta front have the high 900
7 9
est permeabilities at 10-80 mD. Permeabilities between 0.3 and 3 mD are 2HCMS 8
10
11
more common to lower shoreface sediments. The highest amounts of carbo 37o00' 1050
9 12 Middle to
nate cement are present in the lower to middle shoreface. Varying deposi 950 upper (?)
666
tional environments and their changing lithologies create distinctive divi 13 shoreface
er
10
Middle
Riv
Sa
sions in the Point Lookout log responses (Figs. UM-37, -38, and -39). 14
shoreface
n
1100 11
These divisions are used by exploration geologists to correlate productive Jua
NEW MEXICO
12
n 1000
zones. 15 Distal
as 13
Further work in the Mesaverde reveals the Point Lookout shoreface pro Shiprock ni
m lower
A 16
graded in a staircase fashion across the basin, as a series of steps and risers 1150 14 shoreface
Lower 17
until it reached its seaward depositional limit (Fig. UM-36). At this limit, River Farmington shoreface 15 1050
0 10 mi 18
there is a change in the stacking pattern of genetic sequences from seaward 16 19
stepping to landward stepping. This marks the beginning of the Cliff House 17
1200
shoreface aggradation. Reservoir-quality sandstones in the two vertically 18 20 1100
stacked shorefaces at the turnaround position are 70 meters thick. Figure UM-37. Index map showing location of drill holes 1HCMS and 2 HCMS referred to in Figure UM-38 Lower
(modified after Keighin, Zech, and Dunbar, 1993). 21 shoreface
1250
SW NE Innershelf 22 1150
Cliff House Sandstone 1300
1200
Intershelf
transition
Lewis Shale
Figure UM-38. Comparison of depositional facies in the Point Lookout Sandstone, as
Upper Menefee determined from cores, for core holes 1HCMS and 2HCMS (Fig. UM-37). Numbered
arrows indicate locations of thin sections examined. (*) patterns indicate zones of
Lower Menefee mineralogical similarity within depositional environments, as determined by modal point-
count analysis (modified after Keighin, Zech, and Dunbar, 1993).
ne
Point Lookout Sandsto
Sand-rich Coastal Plain Channelbelt Sandstones Marine Shelf Figure UM-36. Diagram of the stacking patterns of genetic
sequences in the Mesaverde Group, and the temporal
reflections among the five formations which compose it
Mud-rich Coastal Plain Shoreface Ravinement surface
(modified after Cross and Lessenger, 1997).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL / UNCONVENTIONAL PLAY TYPE: Basin Margin Mesaverde Oil Play / Central Basin Mesaverde Gas Play 16
COLORADO, NEW MEXICO
JEROME McHUGH
Analog Fields within or near Reservation
NENAHNEZAD MESAVERDE FIELD (OIL)
SOUTHERN UTE NO. 3
San Juan County, New Mexico
nw nw sec 20 T32N R9W
(Oil producing fields belong to Basin Margin Mesaverde Oil Play;
Lewis Shale Gas producing fields belong to Central Basin Mesaverde Gas Play)
R 15 W
Nenahnezad Mesaverde 2300
5100 (Fig. UM-40)
4 3
Location of discovery well: nw sw, sec. 10, T29N, R15W (1970) 2
Producing formation: Cretaceous, Menefee Formation 2645 400
2488
2
(lower part) 0
2573 2290
5200 250 2451
Cliff House Number of producing wells: 0
0
Production: 1025 bbl (1983) T 260 2372 ATOM INCORPORATED
transition 00 2474
Type of drive: pumped 29 27 2421
00 2433 #1 ATOM
Average net pay: 30 feet N 28 sw sec 10 T29N R15W
5300 Porosity: 23% 2623 2331
2000
2968
0
29
0 2344
Twin Mounds Mesaverde
2367
5400 Location of discovery well: se sw sec. 4, T29N, R14W (1954) STRUCTURE CONTOUR MAP
2200
Producing formation: Cretaceous Point Lookout Sandstone Datum: Top Point Lookout Sandstone
Number of producing wells: 0 C. I. = 100' MENEFEE
Production: 654,884 MCFG (1983) 2474 Datum elevations from wells FORMATION
drilled to deeper formations
Gas characteristics: Btu 1,153
2400
5500 Discovery Well
Type of drive: Volumetric with possibly partially active
Menefee water drive Well drilled to offset discovery
Formation Average net pay: 10 feet NENAHNEZAD
Porosity: 25% PAY ZONE DATUM
R 15 W
2600
5600 Permeability: 6 mD
0 POINT
4 3 2 LOOKOUT
0
2800
Point Lookout 16 ?
B Bench 5700 SANDSTONE
Sandstone 5 0
8
C Bench
32 8 T
15 29
3000
D Bench 5800 15
10 N
30 11
0
32 MANCOS
20
10
Transition SHALE
0
3200
interval
5900 0
ISOPACH MAP
Figure UM-40. Structure
Figure UM-39. Log of the Lower Menefee Channel Sandstone
Gamma
Upper Mancos Mesaverde pool stratigraphic
contour map, isopach map,
C.I. = 10'
Induction. and type log for the
Ray Shale units. Well is in the Jerome 15 Channel thickness in feet
Nenhnezad Mesaverde field
McHugh Southern Ute NO. 3, NW,
(modified after Meibos, 1983).
TD 8048' DRL NW sec.20, T32N, R9W, La Plata Discovery Well
County, CO (modified after Harr,
Well drilled to offset discovery
1988, p. 123).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL / UNCONVENTIONAL PLAY TYPE: Basin Margin Mesaverde Oil Play / Central Basin Mesaverde Gas Play 17
COLORADO, NEW MEXICO
A A'
WEST TOE
Basin Margin Dakota Oil Play EXPLANATION
o
mation (Fig. UM-43). This unconformity pro 110 108o S 1/2 NE 1/4 and N 1/2 SE 1/4
Sec. 7, T331/2N R16W
(USGS Designation 2206) gressively truncates older units from northeast Paradox Basin FOUR CORNERS
DISTAL MARINE FACIES
nw nw 23, T32N R20W
to southwest. The upper boundary is con Province
General Characteristics formable with the Mancos Formation. San Juan Basin FOSSILIFEROUS
Province FOSSILIFEROUS
The Basin Margin Dakota Oil Play is both a structural and stratigraphic Reservoirs in the Basin Margin Dakota FOSSILIFEROUS
Ute Mt. Ute. Indian
play on the northern, southern, and western sides of the central San Oil Play are controlled by stratigraphic and 38o 38 o Reservation
FOSSILIFEROUS
Juan Basin, and the southeastern part of the Ute Mountain Ute Indian structural trapping (Fig. UM-44). Successful Bridge Creek Limestone Member
Play Boundary of the Mancos Shale
Reservation (Figs. UM-41 and UM-42). Because of the variability of exploration for lower Dakota Sandstone pro
depositional environments in the transgressive Dakota Sandstone, it is duction is accomplished by careful mapping
difficult to characterize a typical reservoir lithology. Most production of channel sandstones and close attention to
UT CO
has been from the upper marine part of the interval but significant oil and gas shows in the thin porous sand Formation boundary
AZ NM
amounts of both oil and gas also have been produced from the nonmar stones that may develop into channels. burrows
ine section.
?
Reservoirs: The Late Cretaceous Dakota Sandstone varies from dom
SCALE Lower shale member of the Mancos Shale
inantly nonmarine channel deposits and interbedded coal and conglom
erate in the northwest to dominantly shallow marine, commonly bur 0 25 50 miles ?
rowed deposits in the southeast. Net pay thicknesses range from 10 to o o Formation Boundary
110 108
100 ft; porosities are as high as 20% and permeabilities are as high as Mancos Shale Fm.
400 mD. Figure UM-41. Location of Basin Margin Dakota Oil Play (modified Dakota FOUR CORNERS
after Gautier, et al., 1996). Sandstone ne ne 22, T32N R20W
Source rocks: Along the southern margin of the play, the Cretaceous ?
MARINE GRYPHEA
marine Mancos Shale was the source of the Dakota oil. API gravities McELMO
DOME
600
STACKED
(DISTRIBUTORY (?) DELTA PLAIN (?)
MUDSTONE
0 FACIES
CHANNEL OVERBANK
range from 44° to 59°. On the Four Corners Platform to the west, non FACIES FACIES COAL
marine source rocks of the Menefee Formation were identified as the 60
00
Menefee
source (Ross, 1980). The stratigraphically higher Menefee is brought CREVASSE
A
SPLAY
Figure UM-43. FACIES COAL
into close proximity with the Dakota across the Hogback Monocline. UTE
00
STACKED
Correlation of uppermost
50
DOME (DISTRIBUTARY?)
CHANNEL DELTA PLAIN ?
Timing and migration: Depending on location, the Dakota Sandstone SENTINEL PEAK 4000
Jurassic to Mid- FACIES HL OVERBANK ?
burrows FACIES
and Lower Mancos Shale entered the oil window during the Oligocene DOME
Cretaceous rocks in the CREVASSE
to Miocene. In the southern part of the area, migration was still taking Ute Mountain Ute Indian SPLAY FACIES
CLINKER
UTE MOUNTAIN INDIAN RESER VATION Reservation (modified
5000
place in the late Miocene or even more recently. 3000 DELTA PLAIN ?
from Aubrey, 1992). OVERBANK ?
Traps: Fields range in size from 40 to 10,000 acres and most produc
FACIES
COAL
MESA VERDE COAL
tion is from fields of 100-2,000 acres. Stratigraphic traps are typically UT CO A' BASIN
HL
HL
formed by updip pinchout of porous sandstone into shale or coal. AZ NM Middle SOUTH
BARKER
DOME
1000
UTE
Structural traps on faulted anticlines sealed by shale form some of the Canyon DOME LACUSTRINE
CHANNEL FACIES
larger fields in the play. Oil production ranges in depth from 1,000 to
-1000
300
0 OVERBANK FACIES
AND
3,000 feet.
2000
MONOC LI N E LACUSTRINE
0 FACIES CLINOPTILOLITE (?)
Exploration status and resource potential: The first discoveries in Salt Creek
50
37
the Dakota play were made in the early 1920's on small anticlinal Shiprock
CK
Burrow Canyon Fm.
BA
G
structures on the Four Corners Platform. Approximately 30% of the LACUSTRINE FACIES
HO
Rattlesnake Slickrock
oil fields have an estimated total production exceeding 1 MMBO, and 26 km
HL
HL 758 m
HL
the largest field (Price Gramps) has production of 7 MMBO. Future Hogback (16 mi)
HL CLINOPTILOLITE
(2500 ft)
HL
Dakota oil discoveries are likely as basin structure and Dakota deposi HL CLINOPTILOLITE
HL
tional patterns are more fully understood. Figure UM-42. Structure EXPLANATION
METERS FEET
SANDSTONE &
contour map of the basal CONGLOMERATE TROUGH CROSSBEDS 12 40
SCALE
Stratigraphy Dakota Sandstone and SILTSTONE & TABULAR - PLANAR
CROSSBEDS
9 30
Approximate location of discovery 0 12 miles MUDSTONE Horizontal distances are not to
location of oil field 20
The Dakota Sandstone is a coastal plain deposit laid down in front of for named oil field LIMESTONE RIPPLE CROSSBEDS
6
scale and facies relationships are
discovery wells for fields 10 only shown schematically.
the advancing Mancos Sea. In the Ute Mountain Ute Indian Reserva producing from the Basin COAL COVERED
3
Limits of Ute Mountain Ute Indian Reservation 0 0
tion the lower Dakota consists primarily of ribbon-type fluvial sand Margin Dakota Oil Play UNCONFORMITY
BENTONITE
stone bodies and the upper Dakota consists of carbonaceous paludal 300
0 Structure Contour line drawn on base of Dakota Sandstone (modified after Anderson, FACIES BOUNDARY
shales deposited in coastal-plain or deltaic environments. The Dakota 1995).
C. I. = 250 feet HL HARDLAYER (composed
unconformably overlies the fluvial deposits of the Burrow Canyon For of silica and clay and locally
contains feldspar)
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY TYPE: Basin Margin Dakota Oil Play 18
COLORADO, NEW MEXICO
Analog Fields Inside or Near Reservation
(*) denotes field lies inside reservation boundaries AZTEC OIL & GAS AZTEC OIL & GAS AZTEC OIL & GAS
No. 3 MIDDLE CANYON No. 1 MIDDLE CANYON No. 2 MIDDLE CANYON
*Middle Canyon Dakota Field ne se 14 T32N R15W
sw nw 14 T32N R15W ne sw 14 T32N R15W
(Fig. UM-44)
San Juan Co., New Mexico San Juan Co., New Mexico San Juan Co., New Mexico
•Location of discovery well: NE ¼, SW ¼, sec. 14, T32N, R1 W
(September 1969) KB 6656 KB 6665 KB 6699
•Producing formation: Cretaceous Dakota Sandstone
•Number of producing wells: 1
•Production: 4,886 BO (1971)
•Type of drive: Water
•Average net pay: 20 feet
•Porosity: 12.1 %
•Permeability: 0.3 mD
Salt Creek Dakota Field
DATUM Base - Greenhorn Ls DATUM
•Location of discovery well: SW ¼, NW ¼, Sec 4, T30N, R17W
(July, 1958)
•Producing formation: Cretaceous Dakota Sandstone Graneros Sh.
•Number of producing wells: 6 (1977)
•Production: 88,604 BO (1977) Top - Dakota
•Gas characteristics: 51.8 ° API Gravity Sandstone
•Type of drive: Water
•Average net pay: 30 - 40 feet
•Porosity: 16 %
•Permeability: 0.8 mD.
Menefee Mountain Field
•Location of discovery well: NW ¼, NE ¼, Sec 16, T35N, R13W
(July, 1978)
•Producing formation: Cretaceous Dakota Sandstone
•Number of producing wells: 3 (1981)
•Production: 33,356 BO (1981)
•Gas characteristics: 34 ° API Gravity
•Type of drive: Water R 15 W
•Average net play: 15 feet
9 10 11 12
•Porosity: 12 - 14 %
•Permeability: Unknown Producting Zone: DAKOTA 3272-3370'
IPP 123 BO. 7 BWPD 3
16 15 14 2 13
1
4
T
Figure UM-44. Cross section 32
showing producing interval of N
the Dakota Sandstone in the
Middle Canyon Field (modified 21 22 23 24
after Stevensen, 1978). MIDDLE CANYON FIELD
San Juan Co., New Mexico
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY TYPE: Basin Margin Dakota Oil Play 19
COLORADO, NEW MEXICO
DAKOTA CENTRAL BASIN GAS PLAY able. Non-associated gas in the Dakota pool was generated during the flanks and bottom of a large depression and is not 110 o 108o EXPLANATION
(USGS Designation 2205) late mature and postmature stages and probably had a marine Mancos localized by structural trapping (Fig. UM-46). The
Shale source (Rice, 1983). fluid transmissibility characteristics of Dakota Paradox Basin
Province
GENERAL CHARACTERISTICS Timing and Migration: In the northern part of the central San Juan sandstones are generally consistent from the cen
This Dakota Central Basin unconventional continuous-type play is Basin, the Dakota Sandstone and Mancos Shale entered the oil genera tral basin to the outcrop. Hydrodynamic forces, San Juan Basin
Province
contained in coastal marine barrier-bar sandstone and continental flu tion window in the Eocene and were elevated to temperatures appro acting in a basinward direction, have been suggest
vial sandstone units, primarily within the transgressive Dakota Sand priate for the generation of dry gas by the late Oligocene. Along the ed as the trapping mechanism, but these forces are Ute Mt. Ute. Indian
38o 38 o Reservation
stone. It is located in the northeastern part of the San Juan Basin prov southern margin of the central basin, the Dakota and lower Mancos en still poorly understood. The seal is commonly pro
ince and the southeastern corner of the Ute Mountain Ute Indian Res tered the thermal zone of oil generation during the late Miocene (Huff vided by either marine shale or paludal carbona Play Boundary
ervation (Figs. UM-45 to UM-47). man, 1987). It is not known at what point hydrodynamic forces ceous shale and coal. Production is primarily at
Reservoirs: Reservoir quality is highly variable. Most of the marine reached sufficient strength to act as a trapping mechanism, but the ear depths ranging from 6,500 to 7,500 feet.
A'
ly Miocene time is likely for the establishment of the present-day up Exploration status and resource potential: The
A
sandstone reservoirs within the central basin field are considered tight UT
Location
lift and erosion pattern throughout most of the basin. Migration of the Dakota discovery well in the central basin was dril CO of Cross
in that the porosities range from 5% to 15% and permeabilies range
AZ NM Section
from 0.1 to 0.25 mD. Fracturing, both natural and induced, is essential oil in the Dakota was still taking place in the late Miocene, of even led in 1947 southeast of Farmington, New Mexico.
A'
for effective field development. more recently, in the southern part of the San Juan Basin. The Dakota Basin Field, containing the Dakota gas
Traps: The Dakota gas accumulation in the central basin is on the pool, was formed February 1, 1961, by combining
Source Rocks: Quality of the source beds for oil and gas is also vari
several existing fields. By the end of 1993 it had
DOME
600
produced over 4.0 TCFG and 38 MMB condensate.
0
Almost all of the Dakota interval in the central part SCALE
of the basin is saturated with gas, and additional 0 25 50 miles
00 future gas discoveries within the central basin field
60 110 o A 108o
and around its margins are possible.
Figure UM-45. Location of Dakota Central Basin Gas Play (modified after Gautier, et
UTE al., 1996).
00
N
50
DOME
A NW SE A'
SENTINEL PEAK 4000
Dakota Mancos Shale
Mancos Shale
DOME
UTE MOU NTAIN UTE INDIA N RESE RVAT ION Greenhorn Limestone
5000
3000
Twowells Graneros Shale
Twowells
MESA VERDE Twowells
BASIN
main
UT CO
AZ NM
Barker Creek
Dakota 1000
Figure UM-47.
Schematic stratigraphic
body
{ Paguate San
dst one
Dakota Sandstone
Basin cross section of Clay Me
sa Shale
Mancos Shale
Dakota Ute Dome Cretaceous- Jurassic
Strait Dakota rocks in the San Juan Enci
-1000
300
0 Burr Cuber
Canyon Basin. Location of cross o Ca nal C o Sand
2000
section is labeled on nyon anyo stone
Dakota MONOC LI N E
Fm. n
50
0 Figure UM-45 (modified
after Walters, et. al.,
Saltw
ash
mem
ber Bru
} Oak
Can
yon
37 1987).
shy Mem
ber
CK
Bas Jac
BA
in M kpile
G
HO
We em San
stw ber dsto
EXPLANATION ate ne
rC
SCALE Re any
Approximate location of discovery Lower Strata cap on
Figure UM-46. Structure tur Me
mb
Morrison Fm.
for named oil field 12 miles contour map of the Dakota eM er
0 Formation and location of em
ber
Ute Mountain Ute Indian Reservation Boundary C. I. = 250 feet the discovery wells for
fields in and near the
0 Structure Contour line drawn on base of Dakota Sandstone reservation (modified after
300
Anderson, 1995).
UTE MOUNTAIN UTE RESERVATION UNCONVENTIONAL PLAY TYPE: Dakota Central Basin Gas Play 20
COLORADO, NEW MEXICO
Analog Fields in and near Reservation
(*) denotes field lies inside Reservation boundaries 12 9
R131/2W
R14W 11
*Barker Creek Dakota
(Fig. UM-48) CONT
TER
Location of discovery well: se ne 16 - T32N - R14W (1925) WA
2300
AC
0'
T S
Producing formation: Upper Cretaceous Dakota Sandstone, GA GREENHORN
70
T
14
AL
16 14
+3
Paradox Formation 32
IN
'
00
Number of producing wells: 5 (1977) G
N RI
38
Production: 215,279,080 MCFG (1996) O
+
GRANEROS
2400
Gas characteristics: Sweet gas
Type of drive: Gas expansion
23 24 22 23
Pay Zone
Marine
Average net pay: 40 feet 21
Porosity: 14% LA PLATA CO., COLO.
Permeability: 0 - 1500 md, average = 16.5 md SAN JUAN CO., N.M.
2500
SU SU DAKOTA
*Ute Dome Dakota RF R FA
0'
AC CE
Continental
E
80
Location of discovery well: se 35 - T32N - R14W (1921) FA FA
A UL
+3
UL
Producing formation: Cretaceous Dakota Sandstone, 17 T 15 T
'
00
Paradox Formation
0'
2600
40
70
Number of producing wells: 14 (1977)
+
+3
Production: 93,589,058 MCFG (1996)
Type of drive: Combination water drive and volumetric T
Average net pay: 30 feet 32 23
'
00
Porosity: 15% N
2700
39
MORRISON
Permeability: 10 md
+
*Basin Dakota
Location of discovery well: ne nw 4 - T27N - R10W NMPM
(April 1947) 26 E.P.G.N. #6 UTE
0'
+ 380 sw sw 17 - T32N - R14W
Producing formation: Cretaceous Dakota Sandstone
Number of producing wells: 2395
Production: Gas: 2,753,610,459 MCFG
R13W A' San Juan Co., New Mexico
Oil: 27,186,314 BO
Characteristics Gas: 1100 BTU
Oil: 50 ° API Gravity
Type of drive: Gas expansion (upper part), E.P.N.G. E.P.N.G. SO. UNION
Water drive (lower part) No. 6 Ute No. 11 Ute No. 17 Barker
Average net pay: 50-70 feet
Porosity: 5-15%
Permeability: 0.1 - 0.25 md +4200'
A A'
+4000'
Est. Gas - Water Contact GREENHORN
+3800'
GRANEROS
Figure UM-48. Structure contour
map of the top of the Graneros
Shale, cross section, and type log +3600' Pay DAKOTA
for the Barker Creek Dakota Field
Zone
(modified after Matheny, 1978)
+3400' MORRISON
UTE MOUNTAIN UTE RESERVATION UNCONVENTIONAL PLAY TYPE: Dakota Central Basin Gas Play 21
COLORADO, NEW MEXICO
Buried Fault Blocks, Older Paleozoic Play Characteristics of the Buried Fault Figure UM-49. Location of Buried Fault 110
o
108o EXPLANATION
(USGS Designation 2101) Blocks, Older Paleozoic Play Blocks, Older Paleozoic Play and
location of oil and gas discovery wells Paradox Basin
General Characteristics for named fields (modified after Province
In the Ute Mountain Ute Indian Reservation, the Buried Fault Blocks,
The play is based on the occurrence of oil accumulations in fault Older Paleozoic Play consists of the Mississippian Leadville Limestone Peterson, 1996). San Juan Basin
blocks involving pre-Pennsylvanian rocks, mainly in the salt anticline Province
and the Devonian McCracken Sandstone Member of the Elbert Forma
area of the Paradox Basin, and it covers an area of approximately tion. Ute Mt. Ute. Indian
38o 38 o Reservation
7,500 square miles (Fig. UM-49). Most of the structures are associat The McCracken Sandstone (Figs. UM-51 and -53) is mainly a do
ed with the salt anticlines themselves and were growing at the same lomitic sandstone, sandy dolomite, and dolomitic mudstone. Cyclical Play Boundary
time that the salt was moving. fluctuations in relative sea level during McCracken time produced three
McElmo
coarsening-and thickening-upward intervals (parasequence sets) which Location of
discovery well for
Reservoirs: Reservoirs are in porous dolomite or dolomitic limestone correspond to the main reservoir units. Depositional environments named oil field
beds of the Mississippian Leadville Limestone (Figs. UM-50, -52, and UT CO
range from intertidal-supratidal carbonate flat to siliciclastic prodelta
AZ Walker
-53) and the Upper Devonian McCracken Sandstone Member (Figs. and delta front. Reservoir flow units are strongly dominated by silici Creek NM
N. Tocito Hogback
UM-51 and -53) of the Elbert Formation. Reservoirs are as thick as clastic lithofacies, whereas carbonate lithofacies compose major flow Dome Mississippian
200 feet, and porosity varies from 5 to as high as 25% in local cases. barriers and baffles. Table Mesa
Permeability is generally low, but is as much as several hundred mD in The Leadville Limestone (Figs. UM-50, -52, and -53) is Kinder
places. hookian to Osagean in age and rests on top of shaly limestones of the
Ouray Limestone. The Leadville is capped by a major unconformity SCALE
Source Rocks: Probable source rocks are the organic-rich black dolo which has truncated the formation. Two well defined intraformational 0 25 50 miles
mitic shales of the Pennsylvanian Paradox Formation. Migration into markers exist in the Leadville (Fig. UM-57). They are interpreted as 110 o 108o
Leadville or McCracken reservoirs occurred where fault blocks are in major erosional channels caused by upward shoaling cycles that include
structural and (or) depositional contact with the black shale, which is a full suite of environments ranging from shallow marine tidal shelf
commonly highly fractured. 00
through lagoonal and supratidal. The markers represent time strati 2000 10
graphic lines which form the boundaries between depositional units and o
0 37 30'
Timing and Migration: Hydrocarbon generation began as early as separate facies of the Leadville. The Leadville has undergone complex
Permian time and has continued to the present in some cases. Migra
tion into pre-salt reservoirs was probably contemporaneous with the
diagenesis. Moldic porosity and vuggy porosity are common.
A McELMO DOME 00
0
00
0
growth of salt structures. Migration pathways were enhanced by se -1 -2
Cortez
vere fracturing of interbedded organic-rich shale during salt move Bluff 0
10
00
00
ment. -3 00
Durango 0
-4
0
00
Traps: Known traps are on uplifted fault blocks adjacent to salt anti -5 00
0
Ute Mountain Ute -6
clines or swells. Seals are Paradox Formation evaporite beds that
0
00
overlie, or are in fault contact with, Mississippian or Devonian reser Indian Reservation
-7
UTAH o
voirs. Drilling depths range from 7,000-8,000 feet at the Lisbon field, COLORADO 37 00'
and to greater than 10,000 feet in other areas. ARIZONA NEW MEXICO
Sa
0 n
Exploration Status and Resource Potential: Six oil and gas accu
r
ive
Ju
R
mulations produce from pre-salt structural blocks. The largest of these a n
im 0
An 700
as
is the Lisbon field, which is approximately 43 MMBO and 250 BCFG 1000 Navajo
-
Reservoir
in size. The remainder of the fields are noncommercial or marginally Riv
er
Farmington
commercial. The play is only moderately explored with respect to 200
0
smaller structures. Future potential is low to moderate, and based on A'
-5000
-6000
previous production history, undiscovered fields are estimated to be
0
00
small to medium in size and have minimal oil columns.
Chinle River
SAN JUAN BASIN
-2
000 0 o
3000 -3
-400 36 30'
Figure UM-50. Structure Contour Map of the top
0 25 50 Miles
0
of the Mississippian Leadville Limestone and
-100
4000
location of cross section in figure UM-53
0 25 50 Kilometers
(modified from Condon, 1995). DEFIANCE PLATEAU
o o o o
109 30' 109 108 30' 108
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY TYPE: Buried Fault Blocks, Older Paleozoic Play 22
COLORADO, NEW MEXICO
50
Figure UM-51. Isopach map of the
25 o McCracken Sandstone Member of the Elbert 20 o
10
37 30' Formation. Contour intervals are 25 ft 0 37 30'
0
50 (modified from Condon, 1995).
0
50 40
Cortez
50
100
Cortez
0
Bluff 75
25 Bluff 30
25
75
Juan Riv Durango 200 Durango
San er San
Juan Rive
r
0
200
0
Ute Mountain Ute Indian Reservation
Ute Mountain Ute Indian Reservation
75
o o
COLORADO 37 0' UTAH COLORADO 37 0'
NEW MEXICO NEW MEXICO
ARIZONA
75
100
r
ive
r
ive
R
R
0
as
50
as
25
Navajo
im
Navajo
im
An
Reservoir
An
Farmington Farmington Reservoir
25
0
50
100
75
75
200
0 25 50 Miles
o
Chinle River
Chinle River
36 30' o
100 0 25 50 Kilometers 0 25 50 Miles 36 30'
100 0 25 50 Kilometers
o o o o o o
109 30' 109 0' 108 30' 108 0' o
109 0' 108 30' o
108 0'
109 30'
1 2 3 4 5 6 7 A' Figure UM-52. Isopach map of the Mississippian
A Leadville Limestone. Contour intervals are 100 ft
(modified from Condon, 1995).
Molas Formation
Leadville Limestone
Ouray Limestone
Upper member
Precambrian McCracken Sandstone
Elbert Member
McCracken Ss Fm.
Member Precambrian
Aneth
Formation Precambrian 600 feet
Ophir Ignacio Precambrian
Formation Quartzite Vertical
scale
Tintic
Quartzite Figure UM-53. Stratigraphic section of Pre-Pennsylvanian units
in the Ute Mountain Ute Indian Reservation and surrounding
Precambrian area. All logs are gamma ray-neutron, except for log number 6
0 which consists of a spontaneous-potential and resistivity curves.
Horizontal scale is variable (modified from Condon, 1995).
Precambrian
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY TYPE: Buried Fault Blocks, Older Paleozoic Play 23
COLORADO, NEW MEXICO
Analog Field Near Reservation
LISBON FIELD
Lisbon Field STRUCTURAL CROSS-SECTION
(Figs. UM-54 - UM-57)
A LISBON B-615 LISBON C-910 LISBON D-810 LISBON D-610 (PROJ)
A'
Location of discovery well: nw ne ne, sec. 10, T30S, R24E (1959) KB 6307 KB 6255 KB 6643
SW KB 6642
NE
Producing formation: McCracken Sandstone Member of the Elbert
MOLAS
Formation, Leadville Limestone
N
8565 (-2265)
Number of producing wells: 11 -1000 IO
ALT AT LOWER ATOKA
LISBON-McINTYRE FAULT
Production: 1.465 BCFG, <1 MMBO McCracken XS RM
DO FO
A AS LEADVILLE
(1996) PAR OL
IL &M 8635 (-2335)
60 MMBO Leadville (1996) -1400 TRA
ELEVATION (FEET)
ON NE
ERT .
Oil characteristics: 44 API PINK ESTO BR
LIM EM ITE
Average net pay: 39.4 Feet ALL E ON OM
-1800 DW ON .ST OL
RE ST D D Upper Osage - Meramec
Porosity: 0.3 - 16.9% E B AN R H
LIM ERT M N S NC OPHIR SHALE &
Y
KE LY
Permeability: <0.01 - 272 mD RA EL
B IGNACIO FORMATIONS
OU PER RACLE
UP McC SH
A
-2200 H
ET
AN
"C"
Marker
-2600 TD 8895 PRECAMBRIAN
TD 9310
TD 9050
EST. OIL-WATER CONTACT
(-2340' SUBSEA) 0 2000
STRUCTURE MAP
Top - F2 Flow Unit FEET
D
U Figure UM-55. Structure cross-section of Lisbon field (after Cole and Moore, 1996). Middle to Lower Osage
McCRACKEN UNIT "B"
BOUNDARY Marker
LISBON D-810
CHRONOSTRATIGRAPHY ne/se ssc 10, 30S, 24E
9000
PARADOX BASIN GR SONIC
-2800
U
D
N WEST
TERMINOLOGY
EAST 7659
PINKERTON SHALE
MOLAS FORMATIONP(P)
-300
D A'
-1
MISSISSIPPIAN
0
U 20
-16
-1 00
REDWALL LIMESTONE
0
40
0
LIS REDWALL LIMESTONE 7988 Lower Osage or Kinderhook
8000
BO
N -M
OURAY LIMESTONE OURAY
-2600
OURAY LIMESTONE 8119
cIN
-2 TY ELBERT
UPPER ELBERT MBR.
UPPER ELBERT 9150 (-2850)
-1800 8232 Kinderhook
DEVONIAN
00 RE UPPER FORMATION McCRACKEN
-2 0 FA
SS MBR. McCRACKEN
20 UL
ANETH 8348 SANDSTONE
)
40
3 SHALE
0 (-2 T
A
MIDDLE
-2 CT & 8422 ANETH SHALE
NTA
DATA
40 O LOWER
EST. OIL-WATER C
BREAK
0
SIL. Baren of Forams
LYNCH DOLOMITE
-2
ORD. ELBERT
80
U 3000
0
D
LYNCH DOLOMITE
8785 9280 (-2980)
CAMB. OPHIR SHALE
IGNACIO FORMATION
OPHIR SHALE Figure UM-57. Type log for Leadville Limestone unit at Lisbon Field (modified after
3000 PRECAMBRIAN 8976
0 5000 Fouret, 1996)
9000
FEET IGNACIO FORMATION
CI = 200FT 9280
TD 9310
Figure UM-54. Structure contour map of the top of the F2 flow unit for Lisbon field and
location of cross section in Figure UM- 55 (modified after Cole and Moore, 1996). Figure UM-56. Type log for McCracken unit at Lisbon Field (modified after Cole and Moore, 1996).
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL PLAY TYPE: Buried Fault Blocks, Older Paleozoic Play 24
COLORADO, NEW MEXICO
Fractured Interbed Play Permian-Pennsylvanian Marginal
110
o
108o EXPLANATION Figure UM-58. Location
(USGS Designation 2103)
of Fractured Interbed Play
Clastics Gas Play
Paradox Basin (modified after Gautier, et (USGS Designation 2104)
General Characteristics Province al., 1996).
This unconventional continuous-type oil and gas play is oil prone
San Juan Basin General Characteristics
throughout most of the Paradox Basin but is more gas prone to the
Province This hypothetical play, formerly known as the Silverton Delta Play
east close to the ancestral Uncompahgre uplift (Fig. UM-58). The
(Peterson, 1989), has been renamed to more accurately reflect the ge
reasons for this change in character are increased depth of burial and Ute Mt. Ute. Indian
38o 38 o ometry and depositional environment of the reservoir rocks. The Sil
percentage of terrestrial organics to the east. Reservation
verton fan delta is limited to an area near the Colorado-Utah state
Play Boundary line, but marginal clastic rocks extend the length of the ancestral Un
Reservoirs: The play depends on extensive fracturing in the organ
compahgre Uplift (Fig. UM-59). These clastics were deposited as co
ic-rich dolomitic shale and mudstone in the interbeds between evap
alesced outwash fans that intertongue with the cyclic marine deposits
orites of the Pennsylvanian Paradox Formation or carbonate and
of the Pennsylvanian Hermosa Group.
clastic rocks of the related cycles on the shelf of the Paradox evapor
ite basin. These shales and mudstones may be as thick as 130 feet UT CO Reservoirs: Gas shows have been encountered in porous and perme
but are more commonly less than 20 feet thick.
AZ NM able sandstone intervals within the generally arkosic Permian Cutler
Formation in the vicinity of the ancestral Uncompahgre Uplift. Such
Source rocks: These organic-rich black dolomitic shales and mud
potential reservoir rock is present where feldspar and clay were winn
stones are the source rocks for most, if not all, of the oil and gas in
owed out by wave action or fluvial stream flow. For most of the area,
the Paradox Basin. Total organic carbon commonly ranges from 1
the lower part of the Pennsylvanian interval is more likely to contain
to 5% but may be as high as 20%. Oil produced by these source
these beds than the upper part because of the lower original feldspar
rocks typically has 40°-43° API gravity and low sulfur content. SCALE content of the lower part. In the upper part of the Pennsylvanian in
terval, the southeastern Paradox Basin province is more likely to con
Timing and migration: The thermal history of these rich source 0 25 50 miles
110
o
108o tain such beds because of the presence of a large fan delta complex
rocks is determined mostly by depth of burial and to a lesser degree
that provided the necessary depositional environments to clean the
by the added effect of the Oligocene volcanic activity. Pennsylvani
sandstone.
an, Permian, Late Cretaceous, and early Tertiary sediments thicken
110 o 108o EXPLANATION
significantly to the east so that the Pennsylvanian section entered the
Source rocks: This play is dependent on the presence of Desmoinesian,
thermal zone of oil and gas generation at different times depending Paradox Basin organic-rich, dolomitic shale and mudstone in contact or close prox
on location. Close to the Uncompahgre Uplift, Pennsylvanian rocks Province imity to reservoir lithologies. Because this juxtaposition is necessari
may have generated oil as early as the Permian; elsewhere these
San Juan Basin ly close to the ancestral Uncompahgre Uplift, the play is gas prone
rocks may have entered the oil generation zone in the Late Creta
Province due to the preponderance of Type III kerogen from the uplift, as well
ceous and the dry gas zone as late as the Oligocene.
as the depth of burial in the deep trough along the basin margin.
Ute Mt. Ute. Indian
Traps: Fracturing of the shale on structures is a necessary attribute 38o 38 o Reservation
Traps: Trap types are expected to be dominantly combinations of
of this play, but the actual trapping and sealing mechanisms may be
Play Boundary updip pinchouts of permeable sandstone lenses localized on folded
stratigraphic as well as structural because the fractures die out into
and faulted structures. Seals are provided by shale beds as well as by
unfractured shale. Only certain intervals within the total shale thick
reduced permeability due to clay.
ness may be of sufficient richness or be sufficiently fractured for
significant oil production. Depths to potential targets vary greatly
Exploration status and resource potential: Little exploration has
from more than 15,000 feet near the eastern basin margin to less UT CO
taken place within this play and there is no production to date, but
than 5,000 feet on the Four Corners Platform. AZ NM shows have been reported from Permian Cutler sandstone bodies. The
presence of excellent source rocks and structures are factors in its fa
Exploration status and resource potential: Until recently, the on
vor.
ly significant production from this play was from the Cane Creek
Figure UM-59. Location of
Shale in the Lone Canyon field discovered in 1962. Recently, near Permian-Pennsylvnian
by Bartlett Flat field has been developed by directional drilling in Marginal Clastics Gas Play
the Cane Creek Shale at a depth of approximately 9,000 feet. The SCALE (modified after Gautier, et al.,
Cane Creek, Chimney Rock, Gothic, and Hovenweep Shales have 1996).
the most potential due to both organic content and thickness. 0 25 50 miles
o
110 108o
UTE MOUNTAIN UTE RESERVATION CONVENTIONAL / UNCONVENTIONAL/HYPOTHETICAL PLAY: Fractured Interbed Play / Permian-Pennsylvanian Marginal Clastics Gas Play 25
COLORADO, NEW MEXICO
