# S S PECIAL • Chemicals and polymer in lighter

oil fi elds.

Acid gas, a concentrated stream of

hydrogen sulfide and carbon dioxide, is

a new type of injectant seeing applications in EOR. Apache Canada Ltd. has

a pilot in the Zama field in northwestern Alberta that produces about 1,000

bo/d.

Chevron Corp. also injects sour gas

as part

of its

secondgeneration

project

in the

Tengiz

field in Kazakhstan. A Chevron Mar. 13,

2008, presentation to analysts said that

this expansion has increased production Guntis Moritis 

# D RILLING 

# & P RODUCTION



# More US EOR projects start but EOR production continues decline

by 250,000 bo/d. Production Editor

Petroleum Development Oman also

has under development the $1 billion

Harweel sour-gas injection project in



# S PECIA L



# EOR/Heavy Oil Survey

southern Oman. PDO expects production for Phase 2AB of the project to

produce about 60,000

bo/d by 2010, with a potential in the next decade

of production increasing

to 100,000 bo/d from

the 10 fields in the cluster

(OGJ, Nov. 5, 2007, p.

52). About this report...

Every 2 years, the Oil & Gas Journal surveys worldwide projects

that use various injection technologies to enhance oil recovery.

Tables showing the projects surveyed start on p. 47, while the following pages describe events and trends affecting EOR activity

levels. Oil & Gas Journal’s exclusive biennial

enhanced oil recovery (EOR) survey,

p. 47 shows that the number of EOR

projects in the US has increased compared with the last survey taken 2 years

ago. Although the current survey lists

more projects, total production from all

US EOR projects is less than in the last

survey.

Production decline in California

steam injection projects mostly accounts for the lower production, while

new carbon dioxide floods mostly account for the increase in projects.

Outside of the US, the number of

projects continues to increase, although

operators for some of these projects did

not update information listed in the

previous survey (OGJ, Apr. 17, 2006, p.

37).



# Survey description

OGJ published its first EOR survey in

May 3, 1971, and the survey has been a

biennial OGJ feature since 1974.

Tables A through

E (pp. 47-59) list

the projects in the

2008 EOR survey.

Projects listed

are those that

involve injecting

fluids, other than

water or methane,

into a reservoir to

improve or enhance oil recovery.

Operators use the

injectants during

the initial production stage, after the

primary depletion

stage, or after the

secondary production stage, which also is known as

tertiary recovery.

The most common injectants include:

• Steam in heavy oil fields at shallower depths.

• Air for in situ combustion projects.

• Carbon dioxide in lighter oil fields.

• Hydrocarbon miscible gas in

lighter oil fields.

Oil & Gas Journal / Apr. 21, 2008 41

080421ogj_41 41 4/15/08 4:17:11 PM

# D RILLING 

# & P RODUCTION Special Report



# D ENBURY CO

2 

# PROJECT POTENTIAL Fig. 1

**Texas Louisiana** 



## Phase 1

82 million bbl Phase 2

77 million bbl Phase 3

41 million bbl

Phase 4

31 million bbl Phase 5

36 million bbl

Phase 6

26 million bbl

Phase 7

50-90 million bbl Phase 8

30-40 million bbl **Brookhaven**

**Mallalieu**

**Little Creek Olive** 

**Smithdale McComb**  **Martinville Davis** 

**Quitman**

**Heidelberg**

**Summerland Soso**  **Sandersville**

**Eucutta**

**Yellow Creek Cypress Creek**  **Tinsley**

**Lake St. John**

**Cranfield Delta** 

**Citronelle**

**Hastings Fig Ridge** 

**Oyster Bayou Mississippi**  **Jackson**

**dome**

**Sonat MS pipeline**  **Free State pipeline**  **Free State pipeline**  **Delta pipeline Delta pipeline** 

**Gr**

**e en pipeli**  **ne NEJD C**  **O**

**2 pip** 

**el ine** 

Note: For Phases 7 and 8 the tertiary reserves are based on 10-17% recovery factors as of Dec. 31, 2006, estimates. Hastings fie ld is under contract but not owned by Denbury.

Source: Denbury Resources Inc., The future in CO 2 , January 2008.



# US projects

OGJ’s survey shows EOR contributing 643,000 b/d to US oil production (Tables 1 and 2), a 9,700-bo/d

decrease from the 2006 survey.The

production numbers represent the

estimated production at the beginning

of the year.

The survey includes 184 active projects, an increase of 32 compared with

the 2006 survey.

Oil production decline in the mature

thermal heavy-oil projects, mostly in

California, is the main explanation for

production decreasing. Production from

US projects using thermal methods

peaked in 1986 at 480,000 bo/d and

has declined to the current 292,000

bo/d, or 12,000 bo/d less than shown

in the 2006 survey.

Chevron Corp.’s operated Kern River

field remains the largest single EOR

project in the US, producing about

83,000 b/d, based on California Conservation Department statistics. Updated

EOR statistics from Chevron were not available at press time.

Aera Energy LLC, a venture of ExxonMobil Corp. and Shell Inc., produces

95,000 bo/d from 17 projects, but this

is a decrease from the 107,000 bo/d

listed in the 2006 survey.

Oil production from in situ combustion has increased to 17,000 bo/d

or 4,000 bo/d more than in the last

survey. Encore Acquisition Co. has three

projects while Continental Resources

Inc. has 12 in fields in North and South

Dakota as well as in Montana.

The combustion project with the

most production is Continental Resources’ Ceder Hill North Unit in

Bowman County, ND.The company says

the unit produces 11,500 bo/d or an

increase of 3,400 bo/d from the last

survey. Thermal projects typically have

long lives. For instance, the fire flood

in Louisiana’s Bellevue field started in

1970 and the field still produces 280

bo/d, while steam injection started in

California’s Belridge field, now operated by Aera, in 1961; the field currently

produces 33,000 bo/d.

Steam injection projects outside of

California also include a TXCO pilot in

the Maverick basin of South Texas and

MegaWest Energy’s planned pilot in

Vernon County, Mo.

In the US, the number of CO

2 

## miscible injection projects for enhancing

oil recovery has increased (Table 1).

The survey lists 100 ongoing projects

compared with the 79 in the 2006 survey. Enhanced oil recovered from these

projects also has increased to 240,000

b/d from the 235,000 b/d shown in

the previous survey.

Units of Occidental Petroleum Corp.

continue to add CO

2 

## projects. Oxy now

operates 28 projects compared with 27

listed in the 2006 survey.

Denbury Resources Inc. also has

added CO floods. It now has 13 active

2 

## floods compared with 7 listed in the

previous survey. All of its CO

2 

## floods are

in Mississippi except for one in Louisiana. Fig. 1 shows Denbury’s existing

42 Oil & Gas Journal / Apr. 21, 2008

080421ogj_42 42 4/15/08 4:17:14 PM

# D RILLING 

# & P RODUCTION

US EOR PRODUCTION Table 1

1986 1988 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008

Thermal

Steam 468,692 455,484 444,137 454,009 415,801 419,349 439,010 417,675 365,717 340,253 286,668 273,947

Cumbustion

in situ 10,272 6,525 6,090 4,702 2,520 4,485 4,760 2,781 2,384 1,901 13,260 17,025

Hot water 705 2,896 3,985 1,980 250 250 2,200 306 3,360 3,360 4,370 1,776

Total thermal 479,669 464,905 454,212 460,691 418,571 424,084 445,970 417,675 371,461 345,514 304,298 292,748

Chemical

Micellar-polymer 1,403 1,509 617 254 64 0 0 0

Polymer 15,313 20,992 11,219 1,940 1,828 139 139 1,598

Caustic/alkaline 185

Surfactant 20 60 60 60

Total chemical 16,901 22,501 11,856 2,194 1,892 139 139 1,658 60 60 0 0

Gas

Hydrocarbon

miscible/

immiscible 33,767 25,935 55,386 113,072 99,693 96,263 102,053 124,500 95,300 97,300 95,800 81,000

CO

2 miscible 28,440 64,192 95,591 144,973 161,486 170,715 179,024 189,493 187,410 205,775 235,344 240,313

CO

2 immiscible 1,349 420 95 95 66 66 102 2,698 9,350

Nitrogen 18,510 19,050 22,260 22,580 23,050 28,017 28,117 14,700 14,700 14,700 14,700 19,700

Flue gas (miscible and

immiscible) 26,150 21,400 17,300 11,000 –– –– –– ––

Other 6,300 4,400 4,350 4,350 ––

Total gas 108,216 130,997 190,632 298,020 288,629 299,345 313,544 328,759 297,476 317,877 348,542 350,363

Other

Carbonated waterfl ood

Microbial 2 2

Total other 2 2

–––––––– –––––––– –––––––– –––––––– –––––––– –––––––– –––––––– –––––––– –––––––– –––––––– –––––––– –––––––– Grand total 604,786 618,403 656,700 760,907 709,094 723,568 759,653 748,092 668,997 663,451 652,840 643,111



# A CTIVE US EOR PROJECTS Table 2

1988 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008

Thermal

Steam 133 137 119 109 105 92 86 55 46 40 45

Cumbustion in situ 9 8 8 5 8 7 5 6 7 12 12

Hot water 10 9 6 2 2 1 1 4 3 3 3

Total thermal 152 154 133 116 115 100 92 65 56 55 60

Chemical

Micellar-polymer 9 5 3 2

Polymer 111 42 44 27 11 10 10 4 4 0 1

Caustic/alkaline 4 2 2 1 1 1

Surfactant 1 1

Total chemical 124 50 49 30 12 11 10 4 4 0 2

Gas

Hydrocarbon miscible/

immiscible 22 23 25 15 14 11 6 7 8 13 13

CO

2 miscible 49 52 52 54 60 66 63 66 70 79 100

CO

2 immiscible 8 4 2 1 1 1 1 1 2 5

Nitrogen 9 9 7 8 9 10 4 4 4 3 4

Flue gas (miscible

and immiscible) 2 3 2

Other 1 1

Total gas 90 91 89 79 84 87 74 78 83 97 122

Other

Microbial 2 1 1 1

Total other 0 0 2 1 1 1 0 0 0 0 0

–––– –––– –––– –––– –––– –––– –––– –––– –––– –––– –––– Grand total 366 295 273 226 212 199 176 147 143 152 184



## and planned fields. Kuparuk River fi elds. chemical flood is Rex Energy’s plan for

Oxy’s Wasson Denver Unit is the field The survey does not include any US starting two alkali-surfactant-polymer

with the most CO

2 

## EOR production, EOR projects that involve injecting sur­ (ASP) pilots in an old oil field in the

producing 26,850 bo/d. CO

2 

## injection factants, polymers, or other chemicals. Illinois basin in second-quarter 2008.

in the field started in 1983. These projects tend to be smaller and (OGJ, Feb. 11, 2008, p. 39).

Most US hydrocarbon miscible proj­ with shorter lives, and operators chose The pilots will be on 1-acre spacing

ects are on the North Slope of Alaska not to respond to the survey. in Lawrence field, near Bridgeport, Ill.

with the largest in the Prudhoe Bay and One recent announcement on a Lawrence field, discovered in 1906, still

44 Oil & Gas Journal / Apr. 21, 2008

080421ogj_44 44 4/15/08 4:17:15 PM

## Special Report



# C URRENT CO

2 

# SOURCES

produces about 1,800 bo/d from 1,000

wells and Rex Energy says initial oil in

place in the field, the largest in the Illinois basin, was an estimated 1 billion

bbl of which about 400 million bbl has

been produced

Another chemical flood is Cano

Petroleum Inc. alkaline-surfactant-polymer pilot consisting of four wells on

2.5 acres in the Nowata field. ASP injection started toward the end of 2007 and

Cano expects incremental oil production in 2008.



# CO

2 

# availability

Availability of CO

2 

## limits industry’s

ability to expand CO

2 

## EOR flooding

in the US (Fig. 2). Charles Fox, vicepresident of Kinder Morgan Carbon

Dioxide Co., told OGJ that the company

had completed its DOE canyon gas

plant in southwestern Colorado in early

2008, thereby adding 107 MMcfd of

CO

2 

## availability to the Permian basin of

West Texas and New Mexico. He added

that expansion in McElmo dome, also

in Colorado, by mid-2008 will add

another 200 MMcfd of CO

2 

## production

capacity.The addition CO

2 

## form McElmo dome and DOE canyon has been Source: Denbury Resources Inc.,

The future in CO 2 , January 2008 **Great**

**Plains coal**

**gasification plant**

**McElmo dome**

**and DOE canyon**

**St. Johns’ helium**

**and CO 2**  **discovery Sheep** 

**Mountain**

**Bravo**

**dome**

**Gas plants Ammonia** 

**plant**

**Jackson**

**dome** 

### Antrim

**gas plant** 

**La Barge CO**  **2 to Canada**  

## oil field in the baFig. 2 

## sin and for some

other targeted

If both company’s meet their

obligations, EOR

Inc. expects the

pipeline to be

built by late 2010.

Denbury has

plans to increase

its CO

2 

## pipeline,

with one possible

line transporting CO

2 

## into East

Texas. The company also has signed

CO

2 

## purchase contracts with three

planned chemical

plants. In a January presentation,

Denbury said,

contingent on the plants being built, it

expects to obtain:

• 190-225 MMcfd from the Faustina

petroleum coke gasification plant, Donaldsonville, La., starting in 2010.

• 190-225 MMcfd from the USTransCarbon gasification plant, Beaumont,Tex., starting in 2011.

• 350-400 MMcfd from the Rentech

gasification plant, Natchez, Miss., starting in 2011-12.

In Wyoming, Anadarko Corp. has

plans to extend to the Linch-Sussex

area its 125-mile pipeline that currently

transports CO

2 

## to the Salt Creek and

Monell fields.The La Barge gas plant is

the source for this CO .

2



# Canadian EOR

Expansion of in situ production

through steam-assisted gravity drainage (SAGD) and cyclic-steam projects

continues at a rapid pace. Responses to

the survey from some companies along

with information from an Alberta Employment, Immigration, and Industry,

December 2007 report indicate that the

following projects were producing:

• ConocoPhillips Canada began

producing from Phase 1 of its Surmont .dslfi e

already sold to existing projects and

to the North Ward Estes EOR project,

which is the anchor field for deliveries

from DOE canyon, Fox said.

In 2007, Fox noted that the average

amount of CO deliveries to the Perm­

2 

## ian basin was 1.371 bcf/day, broken

down as 966 MMcfd from McElmo

dome, 290 MMcfd from Bravo dome,

40 MMcfd from Sheep Mountain, and

75 MMcfd from Val Verde gas plants.

These deliveries were slightly less than

the 1.388 bcf/day delivered in 2006.

Fox explains that the lower deliveries

were due to an imbalance in demand

and supply during summer 2007. He

expects CO

2 

## deliveries to the Permian

basin during 2008 will set a record.

Enhanced Oil Resources Inc. recently announce a memorandum of

understanding (MOU) for developing a

pipeline with SunCoast Energy Corp. to

carry CO

2 

## 350 miles from its St. Johns,

Ariz., helium and CO

2 

## field to the Permian basin.The company’s initial plans

are to transport 350 MMcfd of CO

2 

## into

the Permian basin.The pipeline design

capacity will be 500 MMcfd.

EOR Inc. has reserved the right to the

first 175 MMcfd of capacity for its own

Oil & Gas Journal / Apr. 21, 2008 45

080421ogj_45 45 4/15/08 4:17:16 PM

### ’ Crawfish • Beer and soft drinks

Barbecue • Live band • Raffles

Children s games • Desserts

Proceeds go to Engineering Scholarships



## Sunday, May 4 /1-5 p.m.

$30/ticket ($35 at the door)



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(entrance #1 – off Spur 5)



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## Thank You 2007 Sponsors For tickets & sponsorship

Information:

contact Diane Ashen, (713) 271-1983 

## SAGD project in 2007 with a designed

capacity of producing 25,000 bo/d.

• Devon Energy Corp. completed

construction of its Jackfish Phase 1

SAGD project with first steaming starting in the third quarter of 2007.

• Connacher Oil & Gas Corp. completed construction at Pod 1 of its Great

Divide SAGD Project. Production started

in the fourth quarter of 2007 and the

company expects to reach 10,000 bo/d

in late 2008.

• Petro-Canada production averaged

22,000 bo/d during third quarter 2007

at its MacKay River in situ project.

• EnCana Energy Corp.’s in situ SAGD

Christina Lake project produces about

6,000 bo/d and its SAGD Foster Creek

project produced 52,000 bo/d.

• Japan Canada Oil Sands (JACOS)

SAGD Hangingstone pilot produces an

average 8,000-8,500 bo/d.

• Total E&P Canada Ltd. started SAGD

production from its Joslyn project in

November 2006 and targets 10,000

b/d for 2008.

• Shell Canada Energy Ltd. started

production from its Orion SAGD project

at yearend 2007. Designed capacity is

10,000 bo/d.

• Canadian Natural Resources Ltd. is

producing 70,000 b/d from its Primrose in situ cyclic steam project.

• Husky Energy started producing

at its Tucker SAGD project, designed for

30,000 bo/d.

• Shell Canada Energy Ltd.’s Peace

River projects produced 18,000 bo/d at

yearend 2007.

• Suncor Energy Inc.’s Firebag SAGD

was producing at about 29,000 bo/d.

• The largest steam project remains

Imperial Oil Ltd’s. Cold Lake, averaging

about 154,000 bo/d in 2007.



# Other countries

Chevron Corp.’s operated Duri field

on Sumatra Island in Indonesia remains

the largest single EOR project in the

world, producing about 190,000 bo/d.

In 2007, Chevron announced the

start of surfactant-polymer pilot in Minas field, the largest field in Indonesia,

with about 4 billion bbl of oil initially in place.The company expects to start

chemical injection in early 2011 and

expects results in 2012.

Chevron also has under construction

the North Duri steamflood that will

start producing in 2008 and is expected

to attain 70,000 bo/d of production.

Another steamflood Chevron has

under construction is in the Neutral

Zone between Suadi Arabia and Kuwait.

Production started in 2007 and Chevron expects production to reach 10,000

bo/d in 2008.

Other countries with active EOR

projects include China and Venezuela,

although the operators did not update

the statistics for these projects.

Petroleos Mexicanos had good

success in increasing oil production

with nitrogen injection in the offshore

Cantarell field , where oil production

increased to more than 2 million b/d in

2004 from the 1 million b/d in 1996.

Currently Cantarell produces about 1.8

million b/d.

Pemex also has started nitrogen

injection in the Ku-Maloob-Zapp, and

Jujo Tecominoacan fields.

Bankers Petroleum Ltd. began a

steam injection pilot in the Patos Marinza in Albania.The Company expects

to drill eight new wells in its thermal

steam project in the fourth quarter of

2008.

Petroleum Development Oman

besides its Harweel sour-gas injection

project, in 2007 started injected steam

in the Amal West field pilot (OGJ, Nov.

5, 2007, pp. 56-65). In 2008, it has

plans to start steam injection pilots in

Amal East and Thayfut fields in 2008.

Other PDO EOR projects under construction are steam projects in Qarn

Alam and Fahud fields, as wells as

a polymer flood in Marmul field. It

expects Qarn Alam to come on stream

in 2010 and produce about 30,000

bo/d and to start in 2008 steam injection in Fahud and polymer injection in

Marmul. In Oman, Occidental is also

developing the Mukhalza steam injection project. ✦

Oil & Gas Journal / Apr. 21, 2008

080421ogj_46 46 4/15/08 4:17:17 PM

# D RILLING 

# & P RODUCTION Special Report



# G UIDE TO EOR TABLES

A. Planned EOR

projects

B. Producing thermal

EOR in US

C. Producing CO

2 , other gas, and

chemical EOR

in US

D. Producing Canadian

EOR projects

E. Producing EOR

outside of US

and Canada 

# A BBREVIATIONS

Formation type Previous production Project maturity Project evaluation Project scope

S: Sandstone Prim: Primary JS: Just started TETT: Too early to tell P: Pilot project

LS: Limestone WF: Waterflood HF: Half fi nished Prom.: Promising FW: Field-wide

Dolo: Dolomite GI: Gas injection NC: Nearing completion Succ.: Successful LW: Lease-wide

Congl.: Conglomerate C: Cyclic steam C: Completed Disc.: Discouraging RW: Reservoir-wide

Tripol: Tripolite HW: Hot water PP: Postponed None: Not evaluated Exp. L: Expansion likely

US: Unconsolidated sand SS: Steam soak Term.: Terminated Exp. UL: Expansion unlikely

S: Steam Del: Deleted

SD: Steam drive TS: Temporarily suspended

SF: Steam fl ood

HC: Hydrocarbon



## Leena Koottungal

Survey Editor 

# 2008 worldwide EOR survey

Size, Depth, Gravity, Start

Type and operator Field Location Pay zone acres ft °API date

CO

2 immiscible

Anadarko Sussex Johnson Co., Wyo. Tensleep 2,544 9,000 29 2010

ARC Energy Trust Redwater Redwater, Alta., T58 R21 W4M Leduc D-3 160 3,000 36 7/08

Denbury Cranfi eld Adams Co., Miss. Lower Tuscaloosa 7,754 10,250 39 5/08

Denbury Heidelberg West Jones & Jasper Co., Miss. Eutaw 915 5,000 22 10/08

CO

2 miscible

Core Energy Chester 6 Otsego, Mich. A1 Carbonate 100 5,700 43 6/09

Core Energy Niagaran “A” Otsego, Mich. Brown Niagaran 120 5,700 43 12/09

Core Energy Niagaran “B” Otsego, Mich. Brown Niagaran 140 5,700 43 12/10

Denbury Delhi Richland, Madison, Holt-Bryant 8,000 3,300 42 1/09

Franklin parishes, La.

Denbury W. Lazy Creek Pike Co., Miss. Lower Tuscaloosa 600 10,250 39 10/09

Fasken Abell Crane Co., Tex., Blk 1C, Devonian 769 5,200 40 1/09

H&TC RR Survey

Fasken River Bend Crane Co., Tex., Blk 1C, Devonian 470 5,300 40 1/09

H&TC RR Survey

Fasken Hanford ROZ Gaines, Tex. San Andres 340 5,700 32 1/09

Kinder Morgan Katz Stonewall Co., Tex. Strawn 5,483 4,800 40 5/09

Occidental North Dollarhide Andrews Co., Tex. Clearfork 270 6,500 40 2008

Petrobras Miranga Brazil onshore Taquipe 1,230 3,940 33 2008

Ridgeway Arizona Oil Milnesand Roosevelt Co., NM San Andres 40 4,600 27 2008

Steam

Carrizo Camp Hill Anderson Co., Tex Carrizo 800 500 19 2008

Derek Oil & Gas Corp. Newcastle Weston Co., Wyo. Newcastle 300 800 20 9/08

MegaWest Marmaton River Vernon, Calif. Warner 10 250 15 2008

Nederlandse Aardolie

Maatschappij (NAM) Schoonebeek Drenthe, Netherlands Bentheim 4,000 2,600 25 2010

Shell Canada Orion Cold Lake, Alta., Township 64 Clearwater 5,120 1,350 10

Range 3 West of 4th

Shell Canada Peace River Peace River Township 84 Bluesky 16,340 1,800 8

R18W5

Wintershall Emlichheim, Block 8/9 North Germany, Lower Saxony, Valanginian 37 2,500­ 25 7/08

Grafschaft Bentheim 2,700

Polymer

CNRL Horsefl y Lake Alberta Mannville 4,500 2,500 22 2009

Petrobras Voador Brazil offshore Marlim 740 8,000 21 2009

Tecpetrol El Tordillo Chubut, Comodoro CR 848 5,500 21 8/08

Rivadavia, Argentina

Tecpetrol El Tordillo Chubut, Comodoro CR 164 5,500 21 2/08

Rivadavia, Argentina

Tecpetrol El Tordillo Chubut, Comodoro CR 82 5,500 21 12/09

Rivadavia, Argentina

Wintershall Bockstedt Lower Saxony, Germany Valanginian 1 3,600­ 24 2010

4,300

Combustion

Petrobras Rio Preto Oeste Brazil onshore Mucuri 1,045 3,380 17 2009

Surfactant-Polymer

Occidental Midland Farms Unit Andrews Co., Tex. Grayburg 4,000 4,800 34 2010

Rex Energy Lawrence Lawrence Co., Tex. Cypress, Bridgeport 2 800-1,400 36-40 2009 

# P LANNED PROJECTS 

# T ABLE A

Oil & Gas Journal / Apr. 21, 2008 47

080421ogj_47 47 4/15/08 4:16:02 PM

# D RILLING 

# & P RODUCTION

No. No. PorosType and Start Area, wells wells Forma­ ity,

operator Field State County date acres prod. inj. Pay zone tion %

Steam

Aera Energy South Belridge Calif. Kern 1961 6,200 2,200 1,000 Tulare US 35

Aera Energy South Belridge Calif. Kern 1995 60 163 62 Diatomite Opal A Tripol 60

Aera Energy Coalinga Calif. Fresno 1965 574 376 68 Temblor S 32

Aera Energy Coalinga Calif. Fresno 1987 290 95 20 Etchegoin S 34

Aera Energy Cymric Calif. Kern 12/86 600 162 147 Tulare S 36

Aera Energy Lost Hills Calif. Kern 8/77 100 246 86 Etchegoin US 40

Aera Energy Lost Hills Calif. Kern 11/75 170 256 94 Tulare US 40

Aera Energy McKittrick Calif. Kern 3/88 160 118 116 Tulare S 36

Aera Energy Midway-Sunset Calif. Kern 11/67 1,600 1,749 167 Potter S 30

Aera Energy Midway-Sunset Calif. Kern 10/70 1,230 1,440 280 Monarch S 25-32

Aera Energy Midway-Sunset Calif. Kern 1984 15 3 0 Sub Lakeview S 30

Aera Energy Midway-Sunset Calif. Kern 1969 50 75 16 Metson S 30

Aera Energy Midway-Sunset Calif. Kern 1988 66 98 19 Marvic S 30

Aera Energy Midway-Sunset Calif. Kern 1980 152 170 1 Tulare S 31

Aera Energy Midway-Sunset Diatomite Calif. Kern 1997 48 38 0 Diatomite 65

Aera Energy San Ardo Calif. Monterey 6/68 125 38 0 Aurignac S 34.5

Aera Energy San Ardo Calif. Monterey 3/80 546 170 49 Lombardi S 32.5

Berry Midway-Sunset Calif. Kern 11/02 15 35 20 Tulare S 30

Berry North Midway-Sunset Calif. Kern 1965 160 125 Potter S 30

Berry South Midway-Sunset Calif. Kern 1964 600 1,200 Monarch S 30

Berry Placerita Calif. Los Angeles 1987 120 50 58 Lower Kraft S 27

Berry Midway-Sunset South Calif. Kern 2005 40 50 4 Main 10-10 S 30

Berry Poso Creek Calif. Kern 2005 200 77 3 Etchegoin/Chanac S 33

Berry North Midway-Sunset Calif. Kern 2006 100 87 0 Diatomite Tripol. 65

Berry Midway-Sunset South Calif. Kern 2007 10 4 0 Diatomite Tripol. 65

Berry Midway-Sunset South Calif. Kern 2007 60 10 1 Monarch S 30

Chevron Cymric 1Y Calif. Kern 1/80 380 510 0 Antelope 58

Chevron Cymric Calif. Kern 5/75 552 360 80 Tulare S 34.8

Chevron Midway Calif. Kern 1964 1,214 2,039 225 Potter US 30

Chevron Midway Calif. Kern 1982 80 123 3 Tulare US 31

Chevron Midway Calif. Kern 1970 1,200 711 69 Spellacy US 30

Chevron West Coalinga Calif. Fresno 6/90 1,291 541 132 Temblor S 34

Chevron Kern River Calif. Kern 9/68 9,660 8,692 1,219 Kern River S 32

Chevron San Ardo Calif. Monterey 7/87 125 92 13 Lombardi S 34

Derek Oil & Gas Corp. LAK Ranch Wyo. Newcastle 4/04 20 1 3 Newcastle S 22

Derek Oil & Gas Corp. Newcastle Wyo. Weston 3/07 30 8 4 Newcastle Sandstone S 22

ExxonMobil South Belridge Calif. Kern 12/87 90 48 24 Tulare S 38

Ivanhoe Energy Midway-Sunset South Calif. Kern 9/01 90 45 40 Antelope S 34

Ivanhoe Energy Midway-Sunset South Calif. Kern 6/02 94 17 17 Antelope S 34

Naftex Edison 27-RT Calif. Kern 7/77 30 65 29 Chanac S 30

Occidental Kern Front Calif. Kern 1981 3,380 580 70 Etchegoin & Chanac SS 30

Occidental North Antelope Hills Calif. Kern 1980 300 44 2 Packwood & Point SS 35

of Rocks

Seneca Resources Midway-Sunset Calif. Kern 1968 320 800 0 Potter Sand US 37

Stockdale Kern Front Calif. Kern 2/93 160 54 6 Etchegoin S 30

Tidelands Wilmington (Parcel A) Calif. Los Angeles 6/96 44 3 2 S Tar US 31

Hot water

Carrizo Camp Hill Tex. Anderson 1994 37 54 25 Carrizo S 37

Chevron San Ardo Calif. Monterey 7/87 700 7 3 Aurignac S 32

Chevron West Coalinga Calif. Fresno 5/73 780 194 180 Temblor S 34

Combustion

Bayou State Bellevue La. Bossier 1970 200 90 15 Nacatoch S 32

Continental Resources Medicine Pole Hills Unit ND Bowman 1985 8,960 15 9 Red River B & C Dolo. 17

Continental Resources West Medicine Pole ND Bowman 2001 14,335 18 12 Red River

Hills Unit B & C Dolo. 17

Continental Resources Cedar Hills North Unit ND Bowman 2002 51,200 125 77 Red River B Dolo. 18

Continental Resources Buffalo SD Harding 1979 7,680 18 5 Red River B Dolo. 20

Continental Resources West Buffalo SD Harding 1987 4,640 11 5 Red River B Dolo. 20

Continental Resources South Buffalo SD Harding 1983 20,800 37 12 Red River B Dolo. 20

Continental Resources West Cedar Hills Unit Mont. Fallon 2003 7,800 12 5 Red River B Dolo. 17

Continental Resources South Medicine Pole ND Bowman 2003 11,500 10 6 Red River B Dolo. 17

Hills Unit

Encore Acquisition Pennel Phase 1 Mont. Fallon 2002 2,924 22 8 Red River A Dolo. 17

Encore Acquisition Pennel Phase 2 Mont. Fallon 2002 10,010 56 24 Red River A Dolo. 17

Encore Acquisition Little Beaver Mont. Fallon 2002 10,400 57 29 Red River A & B Dolo. 17 

# P RODUCING THERMAL EOR IN US

48 Oil & Gas Journal / Apr. 21, 2008

080421ogj_48 48 4/15/08 4:16:03 PMTot. Enh.

Perme- Depth, Gravity, Oil, Prev. Satur. Satur. Proj. prod., prod., Proj. Project

ability, md ft °API Oil, cp °F. prod. % start % end matur. b/d b/d eval. Profi t scope

1,000-3,000 300-1,400 13-14 1,500-4,000 95 Prim. 75 20 NC 33,000 33,000 Succ. Yes FW

1-5 1,000-1,800 28-30 2-50 110 WF 45 20 JS 5,000 1,500 Prom. Yes P

200-2,500 825-1,650 12-13 2,000-10,000 84-98 Prim. 60 10 HF 4,611 4,611 Succ. Yes FW

800-1,000 650-1,000 9-10 11,500-28,000 84 Prim. 55 10 HF 1,692 1,692 Succ. Yes FW

1,000-3,000 1,000 11-14 1,000-2,000 95-105 Prim. 65 20 NC 3,500 3,500 Succ. Yes FW

800-1,500 350 14 1,500-4,000 95 Prim. 55 20 HF 2,200 2,200 Succ. Yes FW

1,000-3,000 200 13 1,500-4,000 82 Prim. 60 20 HF 3,200 3,200 Succ. Yes FW

1,000-2,000 600 10-12 13,000-51,000 83 Prim. 60 20 HF 2,000 2,000 Succ. Yes FW

1,000-4,000 500-1,500 12 91-110 Prim. 60-75 15 HF 14,794 14,794 Succ. Yes FW

700-4,000 800-1,500 13 1,500-5,000 85-100 Prim. 50-75 15 HF 17,850 17,850 Succ. Yes FW

4,500 1,300 13 4,000 90 Prim. 60 15 NC 5 5 Succ. Yes LW

3,000 1,100 11 10,000 130 Prim. 75 15 HF 1,108 1,108 Succ. Yes LW

300 1,100 13 3,500 104 SS 65 15 HF 1,138 1,138 Succ. Yes LW

300-6,000 1,000 11-14 6,000 90 Prim. 60 16 HF 1,230 1,230 Succ. Yes FW

5 0-1,100 12.5 1,000 90 Prim. 75 HF 190 190 Succ. Yes LW

2,000 2,300 12 1,000 130 SS 55 27 NC 496 496 Succ. Yes FW

2,260 2,100 11 3,000 125 SS 55 27 HF 6,285 6,285 Succ. Yes FW

3,500 800 10 10,000 90 CS 60 23 JS 1,000 750 Succ. Yes RW

3,000 1,300 14 4,000 85 Prim. 70 15 NC 550 400 Succ. Yes FW

2,000 1,000 13 8,000 80 Prim. 70 15 HF 10,000 7,000 Succ. Yes FW

1,500 1,800 13 10,000 90 Prim./Cyclic 60 HF 3,000 2,700 Succ. Yes FW, RW,

Exp. L

1,500 1,700 13 8,000 80 Prim./Cyclic 60 JS 400 300 TETT RW

4,000 1,200 13 2,800 110 Cyclic 50 JS 700 650 Prom. FW

1 800 14 SD 65 JS 1,530 1,530 Prom TETT Exp. L,

LW

1 1,100 14 4,000 90 60 JS 25 TETT TETT Exp. L,

LW

800 1,400 14 4,000 90 C 65 JS 200 TETT TETT Exp. L,

LW

5 1,500 13 110 Prim. 20-60 NC 21,200 21,200 Succ. Yes LW

2,700 1,200 12 5,200 100 SS 53 18 HF 10,200 10,200 Succ. Yes LW

3,000 1,500 12 4,000 100 C 60 15 HF 21,000 21,000 Succ. Yes FW

1,300 1,500 11 5,000 100 Prim. 50 43 HF 500 500 Succ. Yes Exp. L

2,250 1,500 12 5,000 100 Prim. 60 20 HF 9,400 9,400 Succ. Yes Exp. L

1,510 1,640 14 3,720 100 SS 44 14 HF 6,558 6,558 Succ. Yes RW

2,000 1,000 13 4,000 90 Prim. 50 15 HF 86,000 86,000 Succ. Yes FW

6,700 1,900 12 1,200 135 C 46 15 HF 2,750 2,750 Succ. Yes P (Exp. L)

100 1,000 16 20 54 NA 85 60 JS 40 40 TETT TETT P

100 800 20 20 54 SD 85 60 C 30 30 Prom. P

2,000 1,250 13 450 95 HF 1,000 800 Succ. Yes FW

200-1,500 900-1,400 15-16 345 100 Prim. 80 60 NC 360 345 Succ. Yes FW

500-2,000 450 11 20,000 80 NA 85 60 JS 200 200 TETT TETT P (Exp. L)

2,800 1,000 14 2,000 90 Prim. 50 15 NC 550 550 Succ. Yes FW

2,000 1,800 14.8 1,525 95 Prim. 45 15 HF 4,000 3,500 Succ. Yes FW

2,500 1,200 13 2,000 80 Prim. 50 35 HF 160 120 Succ. Yes FW

1,000-10,000 1,100-1,700 12 3,000 100 Prim. 65 20 HF 6,000 4,500 Succ. RW

1,000 2,000 13 80 SS 70 JS 700 550 Succ. Yes Exp. L

1,000 2,300 13 300 125 WF 58 28 JS 350 350 Succ. P

3,500 450-500 19 1,200 75 Prim. 65 29 HF 125 100 Succ. LW

2,000 2,100 12 900 135 SF 15 10 NC 253 226 Succ. Yes LW

1,500 1,350 14 3,350 100 SS 48 15 1,450 1,450 Succ. Yes RW

650 400 19 660 Prim. 94 49 HF 240 240 Succ. Yes FW

15 9,500 38 2 230 Prim. 52 30 HF 350 350 Succ. Yes FW

10 9,500 33 2 215 Prim. 50 33 JS 900 900 Succ. Yes FW

10 9,000 33 2 215 Prim. 55 26 JS 11,500 11,500 Succ. Yes FW

10 8,450 31 2 215 Prim. 55 20 NC 525 525 Succ. Yes FW

10 8,450 32 2 215 Prim. 55 20 HF 425 425 Succ. Yes FW

10 8,450 31 2 215 Prim. 55 20 HF 975 975 Succ. Yes FW

10 9,000 33 2 215 Prim. 55 26 JS 725 725 Succ. Yes FW

10 9,200 33 2 220 Prim. 50 30 JS 375 375 Prom. FW

10 8,800 33 1.44 200 WF 75 39 JS 429 160 Succ. Yes Exp. L

10 8,800 33 1.44 200 WF 85 46 JS 1,550 100 Prom. Yes Exp. L

10 8,300 33 1.44 200 WF 83 60 JS 1,650 750 Prom. Yes Exp. L 

# T ABLE B

Oil & Gas Journal / Apr. 21, 2008 49 

## Special Report

080421ogj_49 49 4/15/08 4:16:03 PM

# D RILLING 

# & P RODUCTION

No. No. PorosType and Start Area, wells wells Forma­ ity,

operator Field State County date acres prod. inj. Pay zone tion %

CO

2 miscible

Anadarko Patrick Draw Monell Wyo. Sweetwater 9/03 3,500 56 47 Mesaverde Almond S 20

Anadarko Salt Creek Wyo. Natrona 1/04 3,500 174 153 Wall Creek 2 (Frontier) S 18

Anadarko Salt Creek Wyo. Natrona 5/07 5 1 1 Wall Creek 1 (Frontier) S 17

Anadarko Sussex Wyo. Johnson 12/04 25 4 1 Tensleep S 10

Apache Slaughter Tex. Hockley & Terry 5/85 569 24 11 San Andres Dolo. 12.5

Apache Slaughter Tex. Hockley & 6/89 8,559 228 154 San Andres Dolo. 10

Cochran

Chaparral Energy Sho-Vel-Tum Okla. Stephens 9/82 1,100 60 40 Sims S 16

Chaparral Energy Camrick Okla. Beaver 4/01 2,320 32 19 Morrow S 15

Chaparral Energy North Perryton Tex. Ochiltree 12/07 2,500 6 3 Upper Morrow S 15.2

Chevron Rangely Weber Sand Colo. Rio Blanco 10/86 18,000 378 262 Weber SS S 12

Chevron Mabee Tex. Andrews-Martin 1/92 3,600 220 85 San Andres Dolo. 9

Chevron Slaughter Sundown Tex. Hockley Co 1/94 5,500 155 144 San Andres Dolo. 11

Chevron Vacuum NM Lea Co. 7/97 1,084 48 24 San Andres Dolo. 12

ConocoPhillips South Cowden Tex. Lea 2/81 4,900 43 22 San Andres Dolo. 11.7

ConocoPhillips Vacuum NM Lea 2/81 4,900 192 103 San Andres Dolo. 11.7

Core Energy Charlton 6 Mich. Otsego 2006 60 1 1 Silurian-A1/Niagaran LS/Dolo.

Core Energy Charlton 30-31 Mich. Otsego 2005 285 2 1 Silurian-A1/Niagaran LS/Dolo.

Core Energy Dover 33 Mich. Otsego 1996 120 2 1 Silurian-Niagaran LS/Dolo. 7

Core Energy Dover 33 Mich. Otsego 1996 85 2 1 Silurian-A1/Niagaran LS/Dolo. 5

Core Energy Dover 35 Mich. Otsego 2004 80 2 2 Silurian-Niagaran LS/Dolo. 7

Core Energy Dover 35 Mich. Otsego 2004 70 3 2 Silurian-A1/Niagaran LS/Dolo. 5

Core Energy Dover 36 Mich. Otsego 1997 200 1 2 Silurian-Niagaran LS/Dolo. 7

Core Energy Dover 36 Mich. Otsego 1997 190 1 2 Silurian-A1/Niagaran LS/Dolo. 3

Denbury Resources Lazy Creek Miss. Pike 12/01 840 5 6 Lower Tuscaloosa S 23.4

Denbury Resources Little Creek Miss. Lincoln & Pike 1985 6,200 30 34 Lower Tuscaloosa S 23

Denbury Resources Lockhart Crossing La. Livingston 12/07 3,398 11 3 First Wilcox S 21

Denbury Resources West Mallalieu Miss. Lincoln 1986 8,240 42 31 Lower Tuscaloosa S 26

Denbury Resources Martinville Miss. Simpson 3/06 280 5 1 Mooringsport S 18

Denbury Resources Martinville Miss. Simpson 3/06 212 2 2 Rodessa S 12

Denbury Resources McComb Miss. Pike 11/03 12,600 37 21 Lower Tuscaloosa S 26

Denbury Resources Smithdale Miss. Amite 3/05 4,100 5 3 Lower Tuscaloosa S 23

Denbury Resources Soso Miss. Jones/Jasper/ 4/06 2,600 37 17 Bailey 11701 S 17.4

Smith

Denbury Resources Soso Miss. Jones/Jasper/ 4/06 1,800 16 8 Rodessa 11180 S 16.8

Smith

Denbury Resources Brookhaven Miss. Lincoln 1/05 10,800 31 23 Lower Tuscaloosa S 25.5

Denbury Resources East Mallalieu Miss. Lincoln 12/03 880 11 8 Lower Tuscaloosa S 26

Denbury Resources Tinsley Miss. Yazoo 9/07 10,104 6 Woodruff S 21

Energen Resources East Penwell (SA) Unit Tex. Ector 5/96 1,020 47 22 San Andres Dolo. 10

ExxonMobil Greater Aneth Area Utah San Juan 2/85 13,440 143 120 Ismay Desert Creek LS 14

ExxonMobil Means (San Andres) Tex. Andrews 11/83 8,500 484 284 San Andres Dolo. 9

Fasken Hanford Tex. Gaines 7/86 1,120 23 26 San Andres Dolo. 10.5

Fasken Hanford East Tex. Gaines 3/97 340 7 4 San Andres Dolo. 10

Great Western Drilling Twofreds Tex. Loving,Ward, 1/74 4,392 32 9 Delawar, Ramsey S 19.5

Reeves

George R. Brown Garza Tex. 5/06 650 San Andres

Hess Adair San Andres Unit Tex. Gaines 11/97 1,100 19 18 San Andres Dolo. 15

Hess Seminole Unit-Main Pay Zone Tex. Gaines 7/83 15,699 408 160 San Andres Dolo. 12

Hess Seminole Unit-ROZ Phase 1 Tex. Gaines 7/96 500 15 10 San Andres Dolo. 12

Hess Seminole Unit-ROZ Phase 2 Tex. Gaines 4/04 480 16 9 San Andres Dolo. 12

Hess Seminole Unit-ROZ Phase 1 Tex. Gaines 4/04 480 16 9 San Andres Dolo. 12

Hess Seminole Unit-ROZ Stage 1 Tex. Gaines 12/07 6 2 San Andres Dolo. 12

Kinder Morgan SACROC Tex Scurry 1/72 49,900 391 444 Canyon LS 4

Merit Energy Lost Soldier Wyo. Sweetwater 5/89 1,345 33 39 Tensleep S 9.9

Merit Energy Lost Soldier Wyo. Sweetwater 5/89 790 16 17 Darwin-Madison S/LS-Dolo. 10.3

Merit Energy Lost Soldier Wyo. Sweetwater 6/96 120 11 7 Cambrian S 7

Merit Energy Wertz Wyo. Carbon, 10/86 1,400 12 22 Tensleep S 10

Sweetwater

Merit Energy Wertz Wyo. Carbon, 9/00 810 12 18 Darwin-Madison S/LS-Dolo. 10

Sweetwater

Merit Energy Northeast Purdy Okla. Garvin 9/82 3,400 85 49 Springer S 13

Merit Energy Bradley Unit Okla. Garvin/Grady 2/97 700 29 12 Springer S 14

Murfi n Drilling Hall-Gurney Kan. Russell 12/03 10 2 3 LKC C LS 25

Orla Petco East Ford Tex. Reeves 7/95 1,953 8 4 Delaware, Ramsey S 23

Occidental Alex Slaughter Estate Tex. Hockley 8/00 246 21 14 San Andres Dolo./LS 10

Occidental Anton Irish Tex. Hale 4/97 4,437 112 94 Clearfork Dolo. 7

Occidental Cedar Lake Tex. Gaines 8/94 2,870 159 98 San Andres Dolo. 14

Occidental Central Mallet Unit Tex. Hockley 1984 6,412 182 136 San Andres Dolo./LS 11

Occidental Cogdell Tex. Scurry/Kent 10/01 2,684 93 55 Canyon Reef LS 13 

# P RODUCING CO 2 

# , OTHER GAS, AND CHEMICAL EOR IN US

50 Oil & Gas Journal / Apr. 21, 2008

080421ogj_50 50 4/15/08 4:16:04 PMTot. Enh.

Perme- Depth, Gravity, Oil, Prev. Satur. Satur. Proj. prod., prod., Proj. Project

ability, md ft °API Oil, cp °F. prod. % start % end matur. b/d b/d eval. Profi t scope

30 5,000 43 0.6 120 Prim., WF 39 24 HF 3,000 3,000 Succ. Yes RW, Exp. L

75 1,900 37 0.6 Prim., GI, WF 39 24 JS 5,000 6,000 Succ. Yes RW, Exp. L

30 1,500 35 0.6 99 Prim., WF 39 24 JS Prom. P, Exp. L

16 9,000 30 2.0 200 WF NC Prom. P

6 4,900 32 1 110 WF HF 600 580 Succ. Yes LW

3 5,000 32 2 107 WF 45 8 JS 5,800 4,000 Succ. Yes LW

70 6,200 30 3 115 WF 59 42 HF 1,100 1,100 Succ. Yes FW

63 7,260 38.5 2 152 WF 52 JS 1,275 1,175 Succ. Yes Phase 1&2

(1/2FW)

63 7,300 38 2 152 WF 52 JS 200 170 TETT TETT Phase 1

10 6,000 35 2 160 WF 38 29 JS 15,300 11,600 Succ. Yes FW

4 4,700 32 2 104 WF 36 10 NC 3,100 2,000 Succ. Yes Exp. L

6 4,950 33 1 105 WF 41 25 HF 5,950 4,747 Succ. Yes LW

22 4,550 38 1 101 WF 36 15 HF 4,500 2,950 Succ. Yes LW

11 4,500 38 1 101 Prim. 70 50 JS 450 250 Succ. Yes FW

11 4,500 38 1 101 Prim. 70 50 HF 6,200 5,200 Succ. Yes FW

0.1-100 5,450 43 0.8 103 Prim. 54 44 JS 10 10 TETT Exp. L

0.1-100 5,450 42 0.8 103 Prim. 47 40 JS 75 75 Succ. Exp. L

10 5,400 43 0.8 108 Prim. NC 75 Succ. RW

0.1-100 5,500 43 0.8 100 Prim 51 40 C 0 0 Succ. FW

5 5,400 43 0.8 108 Prim. HF 76 Succ. RW

0.1-100 5,500 41 0.8 101 Prim. 51 35 JS 210 210 Succ. FW

5 5,500 41 0.8 108 Prim. JS 125 TETT RW

0.1-100 5,600 42 0.8 102 Prim. 52 42 HF 70 70 Succ. FW

65 10,400 39 242 Prim. 27.4 JS 250 250 TETT FW

90 10,750 40 250 WF 44 21 NC 1,650 1,650 Succ. FW

50-4,000 10,100 38.9 0.35 212 WF 60.4 JS TETT FW

75 10,550 40 248 Prim. 44 21 HF 6,200 6,200 Succ. FW

40 11,000 38 244 WF 54.7 JS 600 650 Succ. RW

200 11,600 42 250 WF 63.5 JS 180 180 TETT Exp. L

90 10,900 40 250 Prim./WF 52 JS 1,650 1,650 Prom. Exp. L

90 11,000 41 250 Prim. 50 JS 600 600 TETT Exp. L

273 11,950 43 234 Prim. 50.4 JS 1,350 1,350 Prom. Exp. L

171 11,500 45 228 WF 54.7 JS 350 350 Prom. Exp. L

60 10,300 40 250 Prim./GI/WF 47 JS 3,100 3,100 Prom. Exp. L

75 10,550 40 248 Prim./WF 44 JS 1,800 1,800 Prom. Exp. L

289 4,800 33 164 Prim./ WF 24 JS 440 TETT FW

4 4,000 34 2 86 WF 55 40 JS 766 450 Prom. Yes RW

5 5,600 41 1 125 Prim. 50 JS 6,000 3,000 Succ. Yes LW

20 4,300 29 6 97 WF HF 10,000 8,700 Succ. Yes FW

4 5,500 32 1 104 Prim. 60.7 18.7 NC 300 300 Succ. LW

4 5,500 32 1 104 WF 45 18.7 HF 45 45 Succ. LW

32 4,900 36 2 105 WF 50 NC 170 170 Succ. Yes FW

3,000 36

8 4,852 35 1 98 WF JS 2,300 900 Prom. P

1.3-123 5,300 35 1 104 WF HF 19,500 19,500 Succ. Yes FW

1.3-123 5,500 35 1 104 none HF 1,200 1,200 Prom. P

1.3-123 5,500 35 1 104 none HF 1,800 1,800 Prom. P

1.3-123 5,500 35 1 104 none JS 1,800 1,800 Prom. P

1.3-123 5,500 35 1 104 none JS 50 50 Prom. P

19 6,700 39 1 135 Prim./WF 63 39 HF 24,980 24,227 Succ. Yes FW

31 5,000 35 1 178 WF NC 4,672 4,545 Succ. Yes FW

4 5,400 35 1 181 WF NC 2,232 1,661 Succ. Yes FW

10 7,000 35 WF JS 1,740 1,015 Succ. Yes FW

20 6,000 35 1 163 WF NC 3,912 2,986 Succ. Yes FW

5 6,400 35 1 170 WF NC 1,685 1,033 Succ. Yes FW

44 9,400 38 1 148 WF HF 1,800 1,800 Succ. FW

50 9,400 38 1 150 WF JS 800 600 Prom. FW, Exp. L

85 2,900 39.6 3 99 WF 35 NC 3.3 3.3 Disc. No P

30 2,680 40 1 82 Prim. 49 36 HF 128 128 Disc. No FW

5 4,950 31 1.8 105 WF 40 25 HF 370 300 Succ. Yes FW

4 5,800 30 3.0 109 Prim., WF 50 30 HF 5,100 4,000 Succ. Yes Exp. L

5 4,800 32 2.3 102 WF 50 15 HF 4,950 2,860 Succ. Yes LW

2 4,900 31 1.8 105 WF 48 25 HF 2,900 2,100 Succ. Yes FW

6 6,800 40 0.7 130 WF 46 15 HF 6,460 5,900 Succ. Yes Exp. L 

# T ABLE C

Oil & Gas Journal / Apr. 21, 2008 51 

## Special Report

080421ogj_51 51 4/15/08 4:16:04 PM

# D RILLING 

# & P RODUCTION

No. No. PorosType and Start Area, wells wells Forma­ ity,

operator Field State County date acres prod. inj. Pay zone tion %

Occidental El Mar Tex. Loving 4/94 6,000 64 32 Delaware S 22

Occidental Frazier Unit Tex. Hockley 12/84 1,600 67 52 San Andres Dolo./LS 10

Occidental GMK South Tex. Gaines 1982 1,143 16 7 San Andres Dolo. 10

Occidental Igoe Smith Tex. Cochran 9/05 1,235 61 27 San Andres Dolo. 11

Occidental Levelland Tex. Hockley 9/04 1,179 84 51 San Andres Dolo. 12

Occidental Mid Cross-Devonian Unit Tex. Crane, Upton 7/97 1,326 13 5 Devonian Tripol. 18

& Crockett

Occidental N. Cross-Devonian Unit Tex. Crane & Upton 4/72 1,155 26 13 Devonian Tripol. 22

Occidental North Cowden Demo. Tex. Ector 2/95 200 10 3 Grayburg Dolo. 10

Occidental North Dollarhide Tex. Andrews 11/97 1,280 28 20 Devonian Tripol. 22

Occidental North Hobbs NM Lea 3/03 3,100 125 75 San Andres Dolo. 15

Occidental S. Cross-Devonian Unit Tex. Crockett 6/88 2,090 73 30 Devonian Tripol. 21

Occidental Salt Creek Tex. Kent 10/93 12,000 174 135 Canyon LS 20

Occidental Sharon Ridge Tex. Scrurry 2/99 1,400 31 18 Canyon Reef LS 10

Occidental Slaughter (H T Boyd Lease) Tex. Cochran 8/01 1,240 37 24 San Andres Dolo. 10

Occidental Slaughter Estate Unit Tex. Hockley 12/84 5,700 194 150 San Andres Dolo./LS 12

Occidental Slaughter North West Mallet Tex. Cochran & 2008 1,048 39 24 San Andres Dolo. 10

Hockley

Occidental Slaughter West RKM Unit Tex. Hockley 2006 1,204 51 33 San Andres Dolo. 9

Occidental South Welch Tex. Dawson 9/93 1,160 89 70 San Andres Dolo. 11

Occidental T-Star (Slaughter Tex. Hockley 7/99 1,700 51 35 Abo Dolo. 7

Consolidated)

Occidental Wasson Bennett Ranch Unit Tex. Yoakum 6/95 1,780 115 89 San Andres Dolo. 11

Occidental Wasson Denver Unit Tex. Yoakum & Gaines 4/83 27,848 1,010 575 San Andres Dolo. 12

Occidental Wasson ODC Unit Tex. Yoakum 11/84 7,800 325 270 San Andres Dolo./LS 10

Occidental Wasson Willard Unit Tex. Yoakum 1/86 8,500 275 228 San Andres Dolo. 10

Occidental West Welch Tex. Gaines 10/97 240 0 0 San Andres Dolo. 10

Pure Resources Dollarhide (Devonian) Unit Tex. Andrews 5/85 6,183 83 66 Devonian Dolo./Tripo­ 13.5

litic chert

Pure Resources Dollarhide (Clearfork “AB”) Unit Tex. Andrews 11/95 160 21 4 Clearfork Dolo. 11.5

Pure Resources Reinecke Tex. Borden 1/98 700 32 8 Cisco Canyon Reef LS/Dolo. 10.4

Resolute Natural Greater Aneth Utah San Juan 10/98 1,200 12 10 Desert Creek LS 12

Resources

Stanberry Oil Hansford Marmaton Tex. Hansford 6/80 2,010 5 6 Marmaton S 18.1

Whiting Petroleum North Ward Estes Tex. Ward/Winkler 5/07 16,300 816 816 Yates SS 16

Whiting Petroleum Postle Okla. Texas 11/95 11,000 92 82 Morrow SS 16

Whiting Petroleum Postle Expansion Okla. Texas 1/07-1/09 7,000 72 62 Morrow SS 16

XTO Energy Inc. Goldsmith Tex. Ector 12/96 330 16 9 San Andres Dolo. 11.6

XTO Energy Inc. Cordona Lake Tex. Crane 12/85 2,084 64 26 Devonian Tripol. 22

XTO Energy Inc. Wasson (Cornell Unit) Tex. Yoakum 7/85 1,923 90 62 San Andres Dolo. 8.6

XTO Energy Inc. Wasson (Mahoney) Tex. Yoakum 10/85 640 45 30 San Andres Dolo. 13

CO

2 immiscible

Anadarko Salt Creek Wyo. Natrona 10/05 5 4 1 Wall Creek 1 (Frontier) S 17

Chaparral Energy Sho-Vel-Tum Okla. Stephens 11/98 98 6 1 Aldridge S 20

Denbury Eucutta Miss. Wayne 4/06 2,100 25 29 Eutaw S 27

Denbury Martinville Miss. Simpson 3/06 180 3 1 Wash-Fred 8500 S 26

Kinder Morgan Yates Tex. Pecos 3/04 26,000 551 121 San Andres Dolo. 17

Hydrocarbon miscible

BP Alaska Prudhoe Bay Alas. 12/82-2/87 55,000 376 162 Sadlerochit S 22

BP Alaska Eileen West End Alas. 12/02 4,000 40 16 Sadlerochit S 19

BP Alaska Aurora Alas. 12/03 10,000 16 12 Kuparuk River S 20

BP Alaska Borealis Alas. 2004 9,000 31 19 Kuparuk River S 20

BP Alaska Orion Alas. 2006 11,000 9 23 Schrader Bluff S 25

BP Alaska Polaris Alas. 2004 5,000 8 10 Schrader Bluff S 25

BP Alaska Pt. McIntyre Alas. 2001 6,240 55 15 Kuparuk River S 23

ExxonMobil South Pass Block 89 OCS 12/83 204 9 5 X and Y Series S 26

ExxonMobil South Pass Block 89 OCS 7/89 20 3 3 X Series S 26

ConocoPhillips Kuparuk River Alas. 6/88-12/96 70,000 350 260 Kuparuk A&C S 24

ConocoPhillips Tarn Alas. 11/98 2,400 29 11 Bermuda S 21

ConocoPhillips Alpine Alas. 11/00 40,000 25 22 Alpine S 19

Hydrocarbon immiscible

BP Alaska Milne Point Alas. 3/95 20,000 100 90 Kuparuk River S 22

Nitrogen miscible

ExxonMobil Jay-Little Escambia Creek Fla./Ala. Santa Rosa/ 1/81 14,415 53 38 Smackover LS 14

Escambia

Nitrogen immiscible

ExxonMobil Hawkins Tex. Wood 8/87 2,800 27 6 Woodbine-East FB S 28

ExxonMobil Hawkins Tex. Wood 1/94 7,790 267 20 Woodbine-West FB S 28

Occidental Elk Hills Calif. Kern 2005 800 60 Sub Scalez S 28

Chemical, polymer, surfactant

Cano Delaware-Childers Okla. Nowata 6/06 20 Bartlesville

Chaparral Energy North Burbank Okla. Osage 12/07 480 19 9 Burbank S 16.8 

# P RODUCING CO 2 

# , OTHER GAS, AND CHEMICAL EOR IN US (CONTINUED)

52 Oil & Gas Journal / Apr. 21, 2008

080421ogj_52 52 4/15/08 4:16:05 PMTot. Enh.

Perme- Depth, Gravity, Oil, Prev. Satur. Satur. Proj. prod., prod., Proj. Project

ability, md ft °API Oil, cp °F. prod. % start % end matur. b/d b/d eval. Profi t scope

24 4,500 41 1.1 97 Prim./WF 40 NC 350 270 Disc. Yes Exp. UL

4 4,950 31 1.8 105 WF 38 23 HF 1,250 925 Succ. Yes FW

3 5,400 30 3.0 101 WF 55 28 HF 610 375 Succ. Yes LW

4 5,040 34 1.5 105 WF 47 36 HF 700 440 Succ. Exp. L

2 4,900 34 1.4 108 WF 45 30 JS 1,800 950 Succ. Yes Exp. L

2 5,400 42 0.4 104 Prim., GI 60 20 HF 320 296 Disc. Yes FW

5 5,300 44 0.4 104 Prim., GI 49 21 NC 1,045 835 Succ. Yes FW

2-5 4,200 34 1.5 91 WF 40 25 NC 230 80 Succ. Yes P

5 7,500 40 0.5 123 WF 38 23 HF 1,950 1,000 Succ. Yes FW

15 4,200 35 0.9 102 WF 35 24 HF 8,560 6,300 Succ. Yes Exp. L

4 5,200 43 0.6 104 Prim., GI 43 24 HF 5,875 5,790 Succ. Yes FW

12 6,300 39 1.0 125 WF 89 15 HF 7,700 6,600 Succ. Yes LW

70 6,600 43 0.4 125 WF 39 26 HF 900 400 Succ. Yes Exp. L

4 5,000 31 1.6 108 WF 47 36 NC 1,080 1,040 Succ. Yes LW

5 4,950 31 1.8 105 WF 40 23 HF 4,100 2,430 Succ. Yes FW

4 4,950 32 2.0 105 WF 47 31 PP 950 0 TETT

4 4,900 32 2.0 105 WF 42 29 JS 1,560 30 TETT

4 4,900 34 2.3 98 WF 50 15 HF 1,180 865 Succ. Yes Exp. L

2 7,850 28 1.9 134 Prim./WF 75 45 HF 2,100 2,100 Succ. Yes Exp. L

8 5,250 34 1.2 105 WF 55 37 HF 4,320 3,510 Succ. Yes Exp. L

8 5,200 33 1.2 105 WF 51 31 HF 31,500 26,850 Succ. Yes FW

5 5,100 34 1.3 110 WF 49 34 HF 9,900 9,200 Succ. Yes FW

1.5 5,100 32 2.0 105 WF 56 41 HF 4,965 4,765 Succ. Yes Exp. L

3 4,900 34 2.3 98 WF 50 15 C 1,790 0 Disc. No P

9 8,000 40 0 122 Prim./WF 35 22 HF 2,420 1,970 Succ. Yes FW

4 6,500 40 1 113 Prim./WF 30 10 JS 230 124 Prom. Yes Exp. L

170 6,700 43.5 0.4 139 WF 35 10 JS 977 830 Succ. Yes Exp. L

18.3 5,700 42 1.5 129 WF 40 28 JS 1,200 400 Prom. Yes P

48 6,500 44 2 142 Prim. 43 NC 102 102 Succ. Yes FW

37 2,600 36 1.6 83 Prim., WF 26.5 21 JS 4,225 700 Prom. Yes FW

50 6,200 40 1 145 WF 37 25 HF 4,500 4,500 Succ. Exp. L

35 6,200 40 1 145 WF 37 25 1,700 1,700 Early succ. Exp. L

32 4,200 34 0.98 104 WF JS 120 20 TETT P

4 5,500 40 0.50 101 WF HF 1,350 400 Prom. Yes LW

2 4,500 33 1.00 106 WF HF 1,675 800 Succ. Yes LW

6 5,100 33 0.97 110 WF 54.4 39.2 HF 1,875 1,450 Succ. Yes LW

30 1,150 35 0.6 99 Prim., WF 32 24 C Prom. P, Exp. L

270 5,400 19 45 105 Prim. 62 47 JS 72 70 Prom. Yes RW

250 5,050 22 152 WF 42 JS 3,000 3,000 Prom. FW

1,000 8,500 11 198 Prim. 44.3 JS 270 0 TETT RW

175 1,400 30 6 82 GI 75 54 JS 27,940 6,280 Succ. Yes FW

400 8,800 27 0.9 210 WF 50 HF 100,000 28,000 Succ. FW

130 8,800 26 1 235 WF 45 JS 12,000 1,200 Succ. FW

50 6,700 24 2 150 WF 80 JS 9,500 2,600 Succ. FW

100 6,600 24-28 2 160 WF 80 JS 12,700 3,700 Succ. FW

150 4,500 15-23 7-140 85 WF 65 JS 12,500 0 TETT FW

150 4,900 15-23 7-140 100 WF 65 NS 4,000 TETT FW

200 8,800 27 0.9 182 WF 70 HF 30,000 7,000 Succ. FW

1,000-1,500 10,000 38 0.40-0.60 180 Prim. HF 2,100 2,100 Succ. Yes RW

1,000 11,000 38 1 165 Prim. NC 200 200 Succ. Yes RW

50-500 6,000 24 2.0 160 WF/HC Imm. 75 JS 140,000 33,000 Succ. Yes Exp. L

20 5,200 37 0.6 142 None 65 JS 22,000 Succ. Yes RW

20 7,000 40 0.45 160 None 80 JS 95,000 Prom. Yes Exp. L

40 7,000 22 4 170 WF 75 33,600 3,200 Succ. FW

35 15,400 51 0.2 285 WF NC 10,700 10,700 Succ. Yes FW

2,800 4,600 16 25 168 NC 1,500 1,000 Succ. Yes RW

2,800 4,600 24 4 168 JS 9,000 3,000 Prom. RW

1,500 2,500 25 20.0 110 60 10 20,000 5,000

625 32

50 2,900 39 3 122 WF 53 47 JS 110 0 TETT TETT Phase 1 

# T ABLE C

Oil & Gas Journal / Apr. 21, 2008 53 

## Special Report

080421ogj_53 53 4/15/08 4:16:06 PM

# D RILLING 

# & P RODUCTION

P RODUCING CANADIAN EOR PROJECTS

54 Oil & Gas Journal / Apr. 21, 2008 No. No. Poros- PermeType and Start Area, wells wells Forma­ ity, ability,

operator Field Province date acres prod. inj. Pay zone tion % md

Acid gas miscible

Apache Canada Zama-Keg River Alta. 6/04 3,840 12 12 Zama-Keg River Dolo. 8 10-100

CO

2 miscible

Anadarko Canada Enchant Alta. 9/04 3 1 Nisku Dolo. 10-17 10-50

Apache Canada Midale Sask. 10/05 30,483 43 5 Marly & Vuggy Dolo., LS 16.3 7.5

Devon Canada Swan Hills Alta. 10/04 5 1 Beaverhill Lake LS 8.5 54

EnCana Weyburn Unit Sask. 9/00 13,800 403 122 Midale Dolo., LS 15 10

Pengrowth Corp. Judy Creek Alta. 2/07 80 4 1 Swan Hills LS 12 50

Penn West Energy Trust Jofrre Alta 1/84 6,625 33 15 Viking S 13 500

Penn West Energy Trust Pembina Alta. 3/05 80 6 2 Cardium S 16 20

Combustion

Crescent Point Battrum Sask. 10/66 4,920 82 25 Battrum/Roseray S 26 1,265

Energy Trust

Crescent Point Battrum Sask. 8/67 2,400 26 4 Battrum/Roseray S 25 930

Energy Trust

Crescent Point Battrum Sask. 11/65 680 37 9 Roseray S 27 930

Energy Trust

Hydrocarbon miscible

Burlington Resources Brassey B.C. 8/89 6,043 6 6 Artex Triassic S 16.6 137

Burlington Resources Fenn-Big Valley Alta. 4/83 1,268 26 7 Nisku Dolo. 8 400

Conoco Canada Goose River Alta. 4/87 2,847 36 14 Beaverhill Lake/ LS 8-18 3-270

Swan Hills

Devon Canada Swan Hills Alta. 10/85 19,440 400 95 Beaverhill Lake LS 8.5 54

ExxonMobil Oil Canada Rainbow ‘II’ Alta. 7/83 320 2 0 Keg River Dolo., LS 8.5 100-5,000

ExxonMobil Oil Canada Rainbow ‘AA’ Alta. 9/72 800 4 0 Keg River Dolo., LS 8.6 100-5,000

ExxonMobil Oil Canada Rainbow South ‘B’ Alta. 8/72 490 8 3 Keg River Dolo. 6 40

Husky Oil Rainbow KR B Pool Alta. 6/84 2,500 69 11 Keg River Dolo. 8 300

Husky Oil Rainbow South KR Alta. 4/94 478 6 3 Keg River LS 9.1 50

E Pool

Husky Oil Rainbow South KR Alta. 5/95 240 3 2 Keg River LS 8 50

G Pool

Husky Oil Rainbow KR F Pool Alta 6/96 1,920 38 11 Keg River Dolo. 6 1,000

Imperial Oil Pembina `G’ Pool Alta. 9/89 328 2 0 Nisku Dolo. 8 900

Imperial Oil Pembina `K’ Pool Alta. 1984 126 1 0 Nisku Dolo. 12.7 2,020

Imperial Oil Pembina `L’ Pool Alta. 1985 625 4 1 Nisku Dolo. 10.5 1,060

Imperial Oil Pembina `M’ Pool Alta. 1983 192 2 1 Nisku Dolo. 9 540

Imperial Oil Pembina `O’ Pool Alta. 11/83 346 3 0 Nisku Dolo. 11.8 3,100

Imperial Oil Pembina `P’ Pool Alta. 10/83 420 3 1 Nisku Dolo. 10.3 2,400

Imperial Oil Pembina `Q’ Pool Alta. 2/85 301 1 0 Nisku Dolo. 9.8 1,970

Imperial Oil Wizard Lake Alta. 1969 2,725 20 0 Leduc D-3A Dolo. 10.5 1,375

Imperial Oil Rainbow “FF” Pool Alta. 9/71 102 1 0 Keg River Dolo. 7.3 180

Imperial Oil Rainbow “T” Pool Alta. 6/69 222 2 0 Keg River Dolo. 8.6 320

Imperial Oil Rainbow “Z” Pool Alta. 2/71 221 2 1 Keg River Dolo. 4.25 160

Steam

CNRL Tanglefl ags Sask. 1987 285 10 10 Lloydminster S 32.5 3,000-5,000

CNRL Primrose Alta. 1985 160,000 750 Clearwater S 32 2,000-4,000

Devon Canada Athabasca Oil Sands Alta. 7/84 50,000 3 3 McMurray US 30-35 0.1-10

Encana Foster Creek Alta. 5/97 27 27 McMurray S 33 7,000

Encana Christian Lake Alta. 2003 6 6 McMurray S

Husky Oil Pikes Peak Sask. 1/81 400 102 27 Waseca US 33 7,500

Imperial Oil Cold Lake Alta. 1964 4,000 4,000 Clearwater US 35 1,500

Imperial Oil Cold Lake (Enhanced Alta. 2002 32 20 8 Clearwater US 32 2,000

cyclic steam)

Japan Canada Oil Sands Hangingstone Alta. 1997 2,400 15 15 McMurray S

Petro-Canada MacKay Alta. 2002 50 50

Shell Canada Orion Alta. 9/07 5,120 22 22 Clearwater S 33 2,000

Shell Canada Peace River Alta. 1979 4,900 97 109 Bluesky S 26.5 2,000-4,000

Shell Canada Peace River Alta. 10/86 3,000 48 48 Cretaceous-Bullhead S 28.5 100-2,000

Suncor Firebag Alta. 2003

Nitrogen

Talisman Turner Valley Sask. 2001

Polymer

CNRL Pelican Lake Alta. 2006 187,000 1,000 200 Wabiskaw S 29 1,000-4,000

080421ogj_54 54 4/15/08 4:16:06 PM

# T ABLE D

Oil & Gas Journal / Apr. 21, 2008 55 Tot. Enh.

Depth, Gravity, Oil, Prev. Satur. Satur. Proj. prod., prod., Proj. Project

ft °API Oil, cp °F. prod. % start % end matur. b/d b/d eval. Profi t scope

4,900 32-40 0.6-1.5 160-176 Prim. 40 5 JS 1,000 1,000 Prom. Yes Exp. L

4,600 29 2.2 95 WF JS 170 TETT P

4,600 30 3 149 WF 45 JS 5,900 Prom. Yes FW

8,300 41 0.4 225 30 5 JS P

4,655 28 3 140 WF 45 30 JS 20,900 16,500 Prom. LW, Exp. L

8,200 41.5 0.65 206 HC JS TETT P

4,900 42 1.14 133 WF 38 23 HF 700 700 Succ. FW

5,300 41 1 128 WF JS TETT P

2,900 18 70.3 110 Prim. 66 HF 3,200 3,200 Succ. Yes FW

2,900 18 70 110 Prim. 62 HF 800 800 Succ. Yes FW

2,900 18 70 110 Prim. 70 HF 800 800 Succ. Yes FW

9,850 57 0.097 210 98 33 NC 1,500 1,500 Succ. Yes FW

5,249 32.8 1.34 136 Prim. 33 HF 590 590 Succ. Yes FW

9,150 41 0.3 230 WF 55 43 NC 1,900 1,700 Succ. Exp. UL

8,300 41 0.4 225 WF 30 5 NC 14,300 4,100 Succ. Yes FW (Exp. L)

5,500 39 0.46 190 WF 45 15 HF 50 50 Prom. Yes FW

5,500 39 0.47 184 GI/WF 92 15 NC 10 10 Succ. Yes FW

6,200 40 0.3 183 Prim. NC 598 598 Succ. Yes FW

6,000 38 0.83 188 WF 52 23 HF 8,810 8,810 Succ. Yes RW

6,400 43 0.39 195 WF 67 50 Term. 189 189 Disc. Yes RW

6,330 44 0.4 195 WF 67 50 Term. 19 19 Disc. Yes RW

6,000 48 0.25 180 WF/GI 50 35 JS 3,200 3,200 Succ. Yes RW

9,541 43.2 0.33 204 Prim. 80 5 NC 409 409 Succ. Yes FW

9,469 43.6 0.37 198 Prim. 82 5 NC 208 208 Succ. Yes FW

9,415 40.9 0.42 199 WF 88 5 NC 667 667 Succ. Yes FW

9,333 41.1 0.14 198 Prim. 93 5 NC 472 472 Succ. Yes FW

9,332 43.4 0.32 190 Prim. 84 5 NC 198 198 Succ. Yes FW

9,531 45.4 0.36 200 Prim. 87 5 NC 340 340 Succ. Yes FW

9,421 41.3 0.42 196 Prim. 91 5 NC 220 220 Succ. Yes FW

6,500 38 0.54 167 Prim. 93 12 NC 346 346 Succ. Yes FW

4,160 37 0.59 188 Prim. 90 5 NC 17 17 Succ. Yes RW

4,330 40 0.69 188 Prim. 88 5 NC 161 161 Succ. Yes RW

4,040 38 0.547 190 Prim. 73.5 5 NC 418 418 Succ. Yes RW

1,480 13 13,000 66 Prim. 90 38 TBD 5,000 5,000 Succ. Yes TBD

1,600 10-12 40,000-300,000 60 0 60 30 TBD 70,000 70,000 Succ. Yes TBD

500 8 5,000,000 45 85 15 HF 2,500-3,000 2,500-3,000 Succ. Yes Exp. L

1,600 10 500,000 55 85 JS 35,000 35,000

JS 7,000 7,000

1,640 12 25,000 70 85 HF 7,500 7,500 Succ. Yes RW

1,509 10.2 100,000 55 70 HF 154,000 154,000 Succ. FW

1,395 10 200,000 55 CS 70 HF Prom. P

1,000 JS 9,000 9,000 P

JS 30,000 30,000

1,350 10 75,000 60 SAGD 70 10 JS 10,000 TETT Exp. L

1,800 8 40,000-400,000 63 SF, SD, SS 0.8 0.54 HF 13,000 13,000 Succ. Marginal P, Exp. L

1,800 8 100,000 62 80 JS 5,000 5,000 Succ. Exp. L

P

1,500 13 1,000-4,000 60 Prim. 70 40 TBD 40,000 20,000 Succ. Yes TBD 

## Special Report

080421ogj_55 55 4/15/08 4:16:07 PM

# D RILLING 

# & P RODUCTION

No. No. PorosType and Type Start Area, wells wells Forma­ ity,

operator Operator project Field date acres prod. inj. Pay zone tion %

Argentina

Chubut Tecpetrol Polymer El Tordillo 11/05 552 74 15 57 S 24

Brazil

Bahia Petrobras CO

2 immiscible Buracica 1991 1,670 7 Sergi S 22

Bahia Petrobras CO

2 miscible Rio Pojuca 1999 1 Agua Grande S

Espirito Santo Petrobras Steam Fazenda Alegre 2001 1,255 59 Urucutuca S 27

Rio Grande do Norte (RN) Petrobras Steam Estreito 1984 700 Acu S 25

Rio Grande do Norte (RN) Petrobras Steam Alto do Rodrigues 1984 500 Acu S 25

Sergipe Petrobras Steam Carmopolis 1978 200 Barra Itiuba/ S/Congl. 22

Carmopolis

China

Heilongjiang Province Daquin Oilfield Ltd. Polymer Daqing 12/03 1,729 121 87 Saertu S1-2 S 27

Heilongjiang Province Daqing Administra- Polymer Daqing 6/99 124 8 6 Saertu S1-2 S 26

tion Bureau

Xinjiang Province Xinjiang Petroleum Polymer Karamay 5/96 9 4 Karamay Cong. 21

Adm. Bureau

Jilin Province CNPC-Jilin Microbial Fuju 1994 44 44 S 22-26

Dongyin, Shandong Province CNPC-Shengli Bureau Steam Sanjasi 1984 3,162 280 Ng, Ea, El, Ea S 30

Dongyin, Shandong Province CNPC-Shengli Bureau Steam Lean 1989 10,613 658 Ea, Ng S/Congl. 15-30

Liaoling Province CNPC-Liaohe Bureau Steam Gaoshen 2-3 1982 3,583 450 3rd sand S/Dolo. 20-25

Nanyang, Henan Province CNPC-Henan Bureau Steam Jinglou 1986 1,210 177 E S 32

Nanyang, Henan Province CNPC-Henan Bureau Steam Gueheng 1987 1,655 132 E S 27-34

Pnajin, Liaoning Province CNPC-Liaohe Bureau Steam Shu I 7-5 1990 237 38 11 Middle S 25.6

Pnajin, Liaoning Province CNPC-Liaohe Bureau Steam Shu I 1984 5,718 1,149 Middle & Upper S 23-28

Pnajin, Liaoning Province CNPC-Liaohe Bureau Steam Xiao Wa 1992 2,100 311 2nd Dongying, S 27.5

3rd sand

Pnajin, Liaoning Province CNPC-Liaohe Bureau Steam Huanxiling 1985 7,067 1,848 2nd and 3rd sand S 32

Xinjiang Province CNPC-Xinjiang Bureau Steam Karamay 9-1 1984 469 128 41 Qigu S 32

Xinjiang Province CNPC-Xinjiang Bureau Steam Karamay 9-2 1986 444 79 21 Qigu S 32

Xinjiang Province CNPC-Xinjiang Bureau Steam Karamay 9-3 1986 115 62 31 Qigu S 31

Xinjiang Province CNPC-Xinjiang Bureau Steam Karamay 9-4 1988 963 358 32 Qigu S 30

Xinjiang Province CNPC-Xinjiang Bureau Steam Karamay 9-5 - 9-9 1991 2,495 1,136 Qigu S 32

Xinjiang Province CNPC-Xinjiang Bureau Steam Karamay 6 1989 963 211 45 Qigu S 31

Heilongjiang Province CNPC-Daqing Polymer Lamadian-2 1/94 516 21 9 K S 26

Heilongjiang Province CNPC-Daqing Polymer Sarto 1/93 273 36 25 K S 25

Heilongjiang Province CNPC-Daqing Polymer Lamadian-1 6/94 559 25 16 K S 26

Henan Province CNPC-Henan Polymer Shuanghe 2/96 744 12 3 E S 20

Jilin Province CNPC-Jilin Polymer Fuyu 6/93 519 86 21 K S 25

Liaoling Province CNPC-Liaohe Bureau Polymer Huanxiling-16 3/93 346 11 3 B S 28.5

Shandong Province CNPC-Shengli Bureau Polymer Guodao, Pilpt 9/92 138 10 4 N S 32

Shandong Province CNPC-Shengli Bureau Polymer Guodong 1/91 1,008 52 39 N S 33

Shandong Province CNPC-Shengli Bureau Polymer Guodao 12/94 82 40 N S 32

Tianjin City CNPC-Dagang Polymer Gangxi 3-2, West 12/91 255 19 6 N S 31

Tianjin City CNPC-Dagang Polymer Dagang-West 10/91 277 11 6 N S 31

Daqing CNPC, Liupukang Polymer 7/96 3,803 K

Daqing CNPC, Liupukang Polymer 1/97 4,740 K

Shengli CNPC, Liupukang Polymer 8/96 2,989 N

Shengli CNPC, Liupukang Polymer 9/96 1,536 N

Henan CNPC, Liupukang Polymer 9/96 2,717 E

Nemangu CNPC, Nemangu Combustion Kerxing 1996 6

Jilin Province CNPC, Jilin Microbial 4/96

Liaoling Province Qi-40 Steam drive Panjin 1996 1,962

Snadong Cheo-20 Steam drive Dongyi 1996 964

Colombia

Mid. Magdalena Basin Omimex Steam Teca 2/84 3,448 342 Oligocene A & B S 28

Mid. Magdalena Basin Omimex Steam Teca 1/91 60 20 12 Oligocene B S 28

Germany

Lower Saxony, Grafschaft Wintershall Holding AG Steam Emlichheim, Block 1 7/07 55 7 1 Valanginian US 30

Bentheim

Lower Saxony, Grafschaft Wintershall Holding AG Steam Emlichheim, Block 2 6/05 22 4 1 Valanginian US 30

Bentheim

Lower Saxony, Grafschaft Wintershall Holding AG Steam Emlichheim, Block 3 8/01 50 7 1 Valanginian US 30

Bentheim

Lower Saxony, Grafschaft Wintershall Holding AG Steam Emlichheim, Block 4 2/02 22 5 1 Valanginian US 30

Bentheim Northeast

Lower Saxony, Grafschaft Wintershall Holding AG Steam Emlichheim, 2/99 58 8 1 Valanginian US 30

Bentheim Block 5/7 North

India

Gujarat ONGC Polymer Jhalora 6/93 11 4 1 Kalol Sand IX+X S 33

Gujarat ONGC Combustion Balol 3/90 6 4 1 Kalol Sand I US 28

Gujarat ONGC Combustion Lanwa 8/92 10 4 1 Kalol Sand I US 30

Gujarat ONGC Combustion Balol 10/96 3,450 Kalol sand-I

Gujarat ONGC Combustion Santhal 6/96 3,450 Kalol sand-I & II

Gujarat ONGC Combustion Bechraji 11/96 3,120 Kalol sand-I

Indonesia

Pekanbaru PT Caltex Steam Duri 1/85 30,878 2,702 1,068 Pertama - Kedua US 34

Pekanbaru PT Caltex Steam Duri 7/94 27,000 1,093 532 Rindu US 38

Mexico

Bay of Campeche Pemex Nitrogen Cantarell-Akal 5/00 19-22



### 56 Oil & Gas Journal / Apr. 21, 2008 

# P RODUCING EOR PROJECTS OUTSIDE US AND CANADA

080421ogj_56 56 4/15/08 4:16:08 PMTot. Enh.

Perme- Depth, Gravity, Oil, Prev. Satur. Satur. Proj. prod., prod., Proj. Project

ability, md ft °API Oil, cp °F. prod. % start % end matur. b/d b/d eval. Profi t scope

500 5,450 21 5 185 WF 50.9 45.2 JS 2,270 604 Succ. TETT FW

1,970 35 10.5 120 Prim, WF NC Succ. Yes RW

5,900 36 2 183 Prim HF TETT P

500-2,000 2,300 13 825 124 Prim 76 HF 9,500 9,500 Succ. Yes FW

4,000 1,150 15 1,700 100 Prim NC 5,700 5,700 Succ. Yes FW

3,000 1,480 15 2,500 100 Prim NC 2,500 2,500 Succ. Yes FW

200 2,460 21 500 122 NC 3,860 3,860 Succ. Yes FW

611 3,116 32 9.3 113 WF HF 113 Prom. Exp. L

600 3,268 32 9 113 WF 61.1 46.2 JS 684 809 Prom. Prom. P

198 1,063 28 17 74 WF N/A N/A NC N/A N/A Prom. Prom. P

180 935-1,572 31.5 19-31 86 54 NC Succ. Yes Exp. L

5,000 3,673-3,938 11-19 9,200 131 Prim. 65 HF 9,116 9,116 Succ. FW

3,000-4,500 2,885-3,132 11-18 10,000-40,000 129 Prim. 60 HF 21,735 21,735 Succ. FW

2,200 5,081-5,740 16-19 1,000-2,000 150 Prim. 65 HF 10,136 7,868 Succ. RW

1,500-3,000 459-1,936 16-25 9,600-16,000 70-90 Prim. 65 HF 1,965 1,965 Succ. FW

1,351-7,134 513-1,627 14-22 6,000-137,000 66 Prim. 65-73 HF 1,663 1,663 Succ. FW

1,601 3,345 13 15,000-18,900 129 C 65 HF 2,117 920 Succ. RW

560-1,500 2,755-5,051 13-20 620-25,900 118-134 Prim. 65 HF 32,124 25,760 Succ. FW

1,683 3,772-4,592 11-13 4,000-11,000 115-122 Prim. 65 JS 15,020 15,020 Succ. FW

450-512 2,050-3,440 14 700-14,000 104 Prim. 65 HF 59,595 42,122 Succ. FW

3,170 820 16-24 2,000 66 Prim. 65 HF 1,329 1,329 Prom. RW

2,290 754 16-24 2,240 66 Prim. 65 HF 951 951 Prom. RW

1,730 525-1,180 16-24 4,000 65 Prim. 65 HF 913 913 Disc. RW

3,000 656-1,312 16-24 7,200 66 Prim. 65 HF 2,709 2,709 Prom. RW

1,350-2,000 721-1,146 16-24 5,400-54,000 66 Prim. 65 HF 16,632 16,632 Succ. RW

2,500-3,100 853-1,016 16.5-23 6,400-80,000 66 Prim. 65 HF 2,948 2,948 Succ. RW

580 3,212 33 10 108 WF 70 HF 3,313 1,492 Prom. Exp. L

871 3,376 34 9 115 WF 72 NC 8,913 4,149 Succ. Exp. L

622 3,215 33 10 108 WF 70 HF 7,620 4,884 Succ. Exp. L

173 4,568 33 7 162 WF 68 NC 953 391 Succ. Exp. L

180 1,311 31.5 32 87 WF 73 JS 812 53 Prom. RW

908 4,626 30 17 133 WF 65 HF 1,179 596 Succ. Exp. L

875 3,911 15.5 46 154 WF 69 NC 1,072 387 Succ. Exp. L

901 3,921 14 80 149 WF 71 HF 2,084 707 Prom. Exp. L

875 3,911 15.5 46 158 WF 69 NC 3,984 1,026 Prom. RW

412 3,238 21 19 127 WF 60 NC 1,082 446 Succ. Exp. L

538 3,346 21 22 123 WF 60 NC 365 211 Succ. Exp. L

3,215 33

3,376 33.5

3,911 15.5

3,921 13.6

4,560 32.08

1,640-2,065 29

935-1,575 31.5

2,132-3,464 12

2,886-3,149 14-20

1,200 2,100 12.8 2,965 108 Prim. 57 NC 13,000 8,000 Succ. Yes FW

1,200 2,100 12.8 2,965 108 SS 57 10 HF 1,000 500 Disc. No P (Exp. UL)

300-15,000 2,500-2,700 25 175 100 HW 10-90 10-90 JS 300 280 TETT Good FW

300-15,000 2,500-2,700 25 175 100 WF 10-90 10-90 JS 320 320 Prom. Good FW

300-15,000 2,500-2,700 25 175 100 HW 10-90 10-90 HF 470 465 Succ. Good FW

300-15,000 2,500-2,700 25 175 100 HW 10-90 10-90 HF 200 200 Succ. Good FW

300-15,000 2,500-2,700 25 175 100 WF 10-90 10-90 HF 630 615 Succ. Good FW

5,000 4,000 25.7 10 185 Prim. 82 HF TETT P

8,000-15,000 3,440 15.6 100-150 158 Prim. 70 NC 190 190 Succ. P (FW)

8,000-15,000 3,440 13.5 550 158 Prim. 80 HF 165 165 Prom. P (Exp. L)

3,450 15.6

3,450 17

3,120 15.6

1,600 550 22 350 100 Prim. 62 15 NC 190,000 190,000 Succ. Yes FW

1,600 350 22 350 100 Prim. 60 15 NC Succ. Yes FW

HF



### Oil & Gas Journal / Apr. 21, 2008 57 

# T ABLE E Special Report

080421ogj_57 57 4/15/08 4:16:08 PM

# D RILLING 

# & P RODUCTION

No. No. PorosType and Type Start Area, wells wells Forma­ ity,

operator Operator project Field date acres prod. inj. Pay zone tion %

Trinidad

Parrylands New Horizon Steam Block E 7/01 744 6 0 Forest Sands S 36

Forest Reserve Petrotrin CO

2 immiscible Area 2102 6/76 58 6 2 Forest Sands S 32

Forest Reserve Petrotrin CO

2 immiscible Area 2121 1/74 29 2 2 Forest Sands S 30

Forest Reserve Petrotrin CO

2 immiscible Area 2124 1/86 184 3 1 Forest Sands S 31

Forest Reserve Petrotrin CO

2 immiscible EOR 34 - Cyclic 84 NA 11 0 Forest/MLE S 29

Oropouche Petrotrin CO

2 immiscible Oropouche 6/90 175 4 3 Retrench S 30

Oropouche Petrotrin CO

2 immiscible EOR 44 6/90 175 2 0 Retrench S 30

Guapo Petrotrin Steam Guapo 8/76 400 80 12 Cruse E & F S 25

Point Fortin Petrotrin Steam Cruse E 2/86 66 17 7 Cruse E S 31

Point Fortin Petrotrin Steam Parrylands 7/81 86 25 6 Forest S 30

Point Fortin Petrotrin Steam Parrylands E 7/81 86 16 7 Forest S 30

Forest Reserve Petrotrin Steam Phase I Cyclic 8/76 58 8 0 Forest Sands S 31

Forest Reserve Petrotrin Steam Phase I West 12/88 23 3 10 Forest Sands S 30

Forest Reserve Petrotrin CO

2 immiscible EOR 33 6/76 58 2 0 Forest S 32

Forest Reserve Petrotrin CO

2 immiscible EOR 26 1/74 29 0 0 Forest S 30

Forest Reserve Petrotrin CO

2 immiscible EOR 4 1/86 184 4 0 Cruse S 31

Forest Reserve Petrotrin Steam EOR 32 8/76 58 6 0 Forest Sands S 31

Forest Reserve Petrotrin Steam EOR 43 12/88 23 4 0 Forest Sands S 30

Forest Reserve Petrotrin Steam EOR 45 9/94 40 13 0 Forest Sands S 30

Point Fortin Petrotrin Steam Cruse E Pilot 2/86 66 18 5 Cruse E S 31

Palo Seco Petrotrin Steam North Palo Seco 10/69 300 150 40 Lower Morne L’Enfer S 28

Palo Seco Petrotrin Steam Central Los Bajos 2/74 190 110 16 Lower Morne L’Enfer S 28

Forest Reserve Petrotrin Steam Forest Reserve 3/04 20 12 3 UMLE S 32

UMLE Pilot

Forest Reserve Petrotrin Steam Forest Reserve 3/06 23 13 2 Forest Reserve S 32

UMLE Exp. UMLE Exp.

Turkey

Batman TPAO CO

2 immiscible Bati Raman 3/86 12,890 212 69 Garzan LS 18

Venezuela

Maturin, Campo Mulata PDVSA E&P HC Miscible Carito Central 12/96 12,000 45 10 NARICUAL S 8-20

Maturin, Campo Mulata PDVSA E&P HC Miscible Carito Oeste 11/97 9,500 26 5 NARICUAL S 10-20

Maturin, Campo Furrial PDVSA E&P HC Miscible/Water Furrial 8/98 36,769 102 43 NARICUAL S 15

Anzoategui PDVSA E&P Steam Bare (F.O.) 3/85 16,452 55 48 U1,3(YAC.MFB-53) US 31.9

Anzoategui PDVSA E&P Steam Bare (F.O.) 3/87 8,066 66 65 U2,3(YAC.MFB-23) US 28.6

Anzoategui PDVSA E&P Steam Arecuna (F.O.) 2/85 1,668 5 5 5 US 30.7

Anzoategui PDVSA E&P Steam Arecuna (F.O.) 12/83 1,544 15 15 T(YAC.MFA-52) US 30.6

Campo Cerro Negro PDVSA E&P Steam B.E.P.-Cerro Negro 1984 49,090 186 Morichal-Memb. S 35

Campo Jobo PDVSA E&P Steam Jobo 12/69 25,410 88 Jobo Member S 31

Campo Jobo PDVSA E&P Steam Jobo-P.E.T.C. 8/85 267 17 Morichal S 30

Campo Jobo PDVSA E&P Steam Jobo 12/69 34,099 301 Morichal S 30

Campo Pilon PDVSA E&P Steam West Pilon 12/69 1,065 8 Ofi cina-1 S 31

Zulia PDVSA E&P Steam Bachaquero Lago 12/80 343 2 Bachaquero Superior S 23

Zulia PDVSA E&P Steam Lagunillas Lago 2/71 9,343 522 2 Bachaquero S 34

Zulia PDVSA E&P Steam Tia Juana 2/70 1,692 25 Lagunillas Inferior S 31

Zulia PDVSA E&P Steam Lagunillas 4/65 420 59 U.L.H. S 35

Zulia PDVSA E&P Steam Lagunillas 8/64 76 7 L.L. S 33.7

Zulia PDVSA E&P Steam Lagunillas 7/67 618 54 U.L.H. S 35

Zulia PDVSA E&P Steam Lagunillas 1/70 3,025 147 L.L. S 33.7

Zulia PDVSA E&P Steam Lagunillas 4/70 2,565 220 U.L.H. S 35

Zulia PDVSA E&P Steam Lagunillas 8/70 2,114 175 U.L.H. S 35

Zulia PDVSA E&P Steam Lagunillas 11/79 3,101 261 L.L. S 33.7

Zulia PDVSA E&P Steam Lagunillas 10/80 3,565 297 U.L.H. S 35

Zulia PDVSA E&P Steam Bachaquero 11/84 7,795 640 Post-Eocene S 33.5

Zulia PDVSA E&P Steam East Tia Juana 4/59 341 32 L.L. S 33.5

Zulia PDVSA E&P Steam East Tia Juana 2/61 35 7 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 9/64 411 36 L.L. S 38

Zulia PDVSA E&P Steam East Tia Juana 5/68 2,755 201 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 8/68 3,218 250 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 12/68 1,961 168 L.L. S 38

Zulia PDVSA E&P Steam East Tia Juana 3/69 1,768 145 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 8/69 1,642 148 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 12/69 392 36 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 11/74 1,848 135 21 L.L. S 38.1

Zulia PDVSA E&P Steam East Tia Juana 9/86 1,380 144 L.L. S 36

Zulia PDVSA E&P Steam Main Tia Juana 10/63 867 82 L.L. S 38.1

Zulia PDVSA E&P Steam Main Tia Juana 6/66 144 15 L.L. S 38.1

Zulia PDVSA E&P Steam Main Tia Juana 7/67 1,291 114 L.L. S 38.8

Zulia PDVSA E&P Steam Main Tia Juana 7/67 1,500 134 L.L. S 38.1

Zulia PDVSA E&P Steam Main Tia Juana 10/67 2,323 197 L.L. S 38.1

Zulia PDVSA E&P Steam Main Tia Juana 10/67 1,286 86 L.L. S 38.1



### 58 Oil & Gas Journal / Apr. 21, 2008 

# P RODUCING EOR PROJECTS OUTSIDE US AND CANADA (CONTINUED)

080421ogj_58 58 4/15/08 4:16:09 PMTot. Enh.

Perme- Depth, Gravity, Oil, Prev. Satur. Satur. Proj. prod., prod., Proj. Project

ability, md ft °API Oil, cp °F. prod. % start % end matur. b/d b/d eval. Profi t scope

750 850-1,200 16-18 5,000 97 Prim. 80 JS 100 TETT LW

175 3,000 19 16 120 Prim. 56 HF 43 43 Succ. Yes Exp. L

150 2,600 17 32 120 Prim. 60 HF 0 0 Prom. Exp. L

300 4,200 25 6 130 WF 44 TS 78 78 Prom Exp. L

150 2,025 17 11-145 120 Prim.

- C 15 15 Prom Yes Exp. L

36 2,400 29 5 120 Prim. 53 48 HF 32 32 Prom. P

36 2,400 29 5 120 Prim. 53 C 15 15 Prom. No P

300 2,400 11 5,500 100 Cyclic 75 HF 792 792 Succ. Yes RW

95 1,400 17 175 110 Prim. 58 18 HF 325 325 Prom. P

500 1,100 11 5,500 104 Prim. 75 20 HF 89 89 Succ. Yes RW

500 1,100 11 5,000 105 Prim. 75 HF 235 235 Succ. Yes RW

205 1,200 19 32 105 Prim. 57 15 NC 69 69 Disc. No RW

430 1,500 17 160 105 Prim. 67 25 JS 76 76 Disc. No RW

175 3,000 19 16 120 Prim. 56 C 26 26 Succ. Yes Exp. UL

150 2,600 17 32 120 Prim. 60 NA Term. 0 0 Prom. Yes Exp. UL

300 4,200 25 6 130 WF 44 C 176 176 Succ. Yes Exp. L

205 1,200 19 32 105 Prim. 57 C 0 0 Disc. No Exp. UL

430 1,500 17 160 105 Prim. 67 C 17 17 Disc. No Exp. UL

270 1,100 14 250 110 Prim. 70 C 50 50 Disc. No Exp. UL

250 1,400 17 175 110 Prim. 58 HF 254 254 Succ. Yes P

250 1,700 16 550 110 Prim. 70 HF 1,200 1,200 Succ. Yes RW

250 1,500 16 550 105 Prim. 70 HF 800 800 Succ. Yes RW

300 1,700 13 550 100 Prim. 75 JS 307 307 Prom. P

300 1,700 13 550 100 Prim. 75 JS 633 633 Prom RW

58 4,265 13 592 129 78 NC 7,000 7,000 Succ. Yes FW

10-1,000 13,000-14,500 21 - 33 0.1 - 0.5 290 Prim. 80 JS 150,000 80,000 Succ yes FW

10-1,000 13,000-14,500 24 - 36 0.1 - 0.5 290 Prim. 80 JS 80,000 45,000 Succ yes FW

600 13,000-14,300 26 0.5 290 WF 75 JS 410,000 41,000 Prom yes FW

6,600 2,650 9.3 376 131 Prim. 88 75 HF 65,000 20,000 Succ. Yes RW (Exp. L)

5,000 3,050 9.2 351 136 Prim. 83 75 HF 4,500 500 Succ. Yes RW (Exp. L)

5,800 2,850 10 370 135 Prim. 82 74 NC 0 0 Disc. No P (Exp. UL)

4,500 3,150 9.8 560 140 Prim. 80 72 NC 0 0 Prom. Yes RW

10,000 2,000 8.5 5,500 125 Prim. 80 HF 650 400 Succ. Yes P (Exp. L)

2,500 3,260 13.5 138 130 Prim. 80 HF 14,101 0 Succ. Yes FW

5,000 3,600 9 1,952 132 Prim. 85 NC 1,530 0 Succ. Yes P (Exp. L)

5,000 3,600 9 1,952 132 Prim. 85 JS 5,607 514 Succ. Yes FW

8,000 3,350 10 727 139 Prim. 82 JS 23,912 0 Succ. Yes RW

1,500 3,400 14 185 135 Prim. 85 JS 32,517 17,997 Succ. Yes P (Exp. L)

4,000 2,690 12 600 128 Prim. 84 HF 44,219 31,135 Succ. Yes FW

1,250 2,537 15 93 119 72 HF 5,916 3,815 Succ. Yes P(Exp. L)

2,300 11.4 3,500 117 Prim. 75 44 NC 2,318 2,318 Succ. Yes FW

2,850 15.2 2,500 125 Prim. 80 50 NC 257 257 Succ. Yes FW

2,300 11.4 3,500 117 Prim. 75 46 NC 2,629 2,629 Succ. Yes FW

2,850 15.2 2,500 122 Prim. 87 54 HF 2,675 2,675 Succ. Yes FW

2,300 11.8 7,000 115 Prim. 75 54 HF 21,016 21,016 Succ. Yes FW

2,300 11.4 3,500 118 Prim. 75 63 HF 5,872 5,872 Succ. Yes FW

2,850 15 580 126 Prim. 87 66 HF 4,399 4,399 Succ. Yes FW

2,300 11 20,000 125 Prim. 75 63 HF 19,920 19,920 Succ. Yes FW

575 2,000 13 500 117 Prim. 84.5 40 JS 15,190 15,190 Succ. Yes FW

2,500 1,500 12 1,000 108 Prim. 85 48 HF 470 470 Succ. Yes FW

1,300 1,746 13.6 13,000 100 Prim. 85 45 NC 171 171 Succ. Yes P

3,000 1,250 12 3,000 104 Prim. 85 65 HF 489 375 Succ. Yes FW

1,200 12 750 104 Prim. 85 64 HF 4,806 4,139 Succ. Prom. FW

3,000 872 12 5,000 104 Prim. 81 74 HF 7,778 7,257 Succ. Yes FW

1,250 12 7,500 106 Prim. 85 67 HF 6,415 6,052 Succ. Yes FW

780 1,700 12.1 2,000 111 Prim. 85 67 HF 4,233 3,636 Succ. Yes FW

1,300 1,250 10 12,000 102 Prim. 85 77 HF 5,316 5,316 Succ. Yes FW

1,000 11.1 10,000 95 Prim. 85 72 HF 963 963 Succ. Yes FW

780 1,597 12 1,000 111 Prim. 85 46 HF 2,100 2,100 Succ. Yes FW

1,000-4,000 760 9-11 5,000-30,000 110 Prim. 85 82 HF 6,857 6,857 Succ. Yes FW

1,400 1,750 13.1 750 113 85 57 NC 842 842 Succ. Yes FW

675 1,250 13.1 1,300 104 Prim. 85 65 NC 120 120 Succ. Yes FW

675 1,209 13.1 5,000 123 Prim. 85 61 HF 3,412 3,412 Succ. Yes FW

1,000 1,400 13.1 1,000 110 Prim. 85 65 HF 4,224 4,224 Succ. Yes FW

1,000 1,746 13.1 4,100 110 Prim. 85 62 HF 4,264 3,878 Succ. Yes FW

1,000 1,746 13.1 1,200 110 Prim. 85 76 HF 1,129 1,129 Succ. Yes FW



### Oil & Gas Journal / Apr. 21, 2008 59 

# T ABLE E Special Report

080421ogj_59 59 4/15/08 4:16:10 PM