Delta Petroleum Corporation Provides Update on Production,

Drilling and Other Operating Activities 
DENVER, July 25 /PRNewswire-FirstCall/ -- Delta Petroleum Corporation
(Nasdaq: DPTR); (FRANKFURT STOCK EXCHANGE: DPE), an independent energy
exploration and development company, today provided the following update its
production, drilling and other operating activities. 
PRODUCTION AND RESERVES 
At the date of the Company's last operations update on May 9, 2005,
management indicated that nine wells had been drilled and cased and were
waiting on completion.  The Company estimated that that those nine wells would
add 6 to 10 million cubic feet equivalents (Mmcfe) to the Company's daily
production.  As of June 30, 2005, seven of the nine wells have been completed,
with one well experiencing first sales in late May and the other six wells
coming on line during the month of June.  The seven wells added an aggregate
stabilized initial net production of 7.6 Mmcfe per day, and by the end of June
such aggregate net production approximated 6.4 Mmcfe per day.  The two wells
that were not completed by June 30, 2005 are located on leases administered by
the federal government and are subject to winter restrictions on surface
occupancy that continued later in the year than originally expected.  The two
wells should be completed by the end of August. 
A total of 16 wells were completed and/or recompleted and began producing
since the May 9, 2005 operations update.  These 16 wells, including the seven
discussed above, recorded an aggregate stabilized initial net production of
approximately 14.12 Mmcfe per day and are currently producing at an aggregate
net rate of approximately 12.02 Mmcfe per day. 
For the quarter ended June 30, 2005, the Company's production approximated
4 billion cubic feet equivalents (Bcfe).  Although a June 30, 2005 reserve
report is currently in preparation by the Company's outside reserve
engineering firm, internal estimates indicate that proved reserves should
approximate 220 to 225 Bcfe as of June 30, 2005.  The Company's average annual
decline rate for its entire portfolio approximates 29%.  As we focus our
efforts in the Rocky Mountain Region we expect our corporate decline rate to
dramatically reduce. 
Delta expects drilling capital expenditures to total $55 million to
$60 million during the second half of calendar 2005, approximately 55% of
which will occur in the Rocky Mountain Region.  During fiscal year 2005,
approximately 45% of drilling capital expenditures involved the Rocky Mountain
Region.  Over 60% of drilling capital expenditures forecast in calendar year
2006 are budgeted for the Rocky Mountain Region. 


     DRILLING ACTIVITY
     Howard Ranch:


 At the Howard Ranch development project in the Wind River Basin of
Wyoming the Diamond State 36-31 (Delta Working Interest of 100%) reached total
depth of 17,500 feet on May 25, 2005.  Production casing was set and
completion activities were underway by early June.  To date, eight fracture
stimulations, including four stages in the Mesaverde Formation, have been
completed.  A total of 1,377 feet of an estimated 1,750 foot thick Mesaverde
interval was drilled, and the productive potential of the Mesaverde Formation
appears very encouraging.  In addition, one frac stage in the Meteetsee
Formation, which appears to be only moderately productive, and three frac
stages in the lower Lance section, have been completed.  The productive
potential of the Lance Formation also appears very encouraging.  The existing
three fracture stimulation stages in the Lance tested only approximately 12%
of the total prospective Lance sands. 
Of the intervals completed so far the first two frac stages are in the
middle Mesaverde and experienced an initial flow back rate of 2.5 Mmcfe per
day.  The next two frac stages were in the upper Mesaverde and had an initial
flow back rate of 1.2 Mmcfe per day.  Frac stages five and six were in the
Meteetsee and lowest Lance and had an initial flow back rate of 0.9 Mmcfe per
day.  Frac stages seven and eight were in the lower Lance and had an initial
flow back rate of 1.2 Mmcfe per day.  Currently the well is flowing back from
all eight stages and a total combined rate will be better determined when the
well has recovered its frac load.  We will continue with as many as
10 additional frac stages in the remaining Lance sands. 
Although it is early, management is very encouraged by the well and
believes that the estimated ultimate recovery* (EUR*) from the well will
approximate 8 Bcfe.  Since only 20% of the net pay was completed and producing
as of June 30, 2005, only a portion of the reserves will be included in the
proved category at fiscal year end.  As additional zones are completed,
probable reserves* will convert into proved reserves.  This conversion will
apply to unopened intervals in the Diamond State 36-31 and its four direct
offset locations. 
The Diamond State 36-13 (WI of 100%) is currently drilling at a depth of
13,800 feet with DHS Drilling Company Rig #1.  The well is located
approximately three-quarters of a mile southwest of the Diamond State 36-31
and is expected to reach total depth of approximately 18,000 feet in the
Mesaverde Formation in late August or early September 2005. 
A completion rig has been set on the West Madden 6-27 well (WI of 100%).
The current operation will test each open zone individually to identify and
isolate water bearing zones that have been restricting gas production.  This
operation should be completed in three to four weeks and the well returned to
full time production. 
Newton Field: 
In the Newton Field in Newton County, Texas (Delta WI of 100%), current
net production approximates 8.0 Mmcfe per day, compared with net daily
production of approximately 4.8 Mmcfe per day in January 2005.  A total of
eight wells have been drilled since development of the field began in November
2004, and approximately 40 additional wells are planned to fully develop the
field.  Integration of geological, geophysical and engineering data has
recently been completed, and management believes that only two of the
top 20 locations have been drilled.  Future drilling will be prioritized on
those locations that have the highest expected present value and reserve
recovery.  At the time field development began, the Company focused on those
wells that could be drilled first, either because permits were available or
surface locations were ready.  Future drilling is expected to provide higher
per-well reserves and higher production than the wells drilled to date. 
Delta is currently acquiring seismic data for a 50 square-mile 3-D survey
around the Newton Field and expects data acquisition to be completed by the
end of August.  The data should be fully processed and interpreted by calendar
year end. 
South Angleton Field: 
In the South Angleton Field in Brazoria County, Texas (Delta WI ranging
from 50% to 100%) current net daily production approximates 750 Mcfe.  This
field was originally acquired in June 2004.  Our initial evaluation estimated
six potentially high volume drilling opportunities that, while not viewed as
long-term growth projects, were expected to provide significant near term
production.  Four of these locations have now been drilled, and the
recompletion of another well has been attempted.  The most recent of the four
wells (Delta Prison Farms #1; WI of 50%) reached total depth on July 14, 2005,
but has not yet been completed.  This well exhibited very good mud log shows
but its productive capability will be unknown for several weeks.  Overall
results have been disappointing in the South Angleton Field, as the Company
has spent in excess of $10 million on drilling capital expenditures without
adding significant additional reserves or production.  At this time,
management does not contemplate significant future development in the field. 
Other Gulf Coast Activities: 
The Company expects to have a drilling rig available within the next two
weeks for a series of five shallow Wilcox tests in the Opossum Hollow Field
(WI of 98%) in McMullen County, Texas.  In addition, a deep Sligo test (WI of
98%) should be drilled in the field by calendar year end. 
Piceance Basin: 
In the Piceance Basin in Northwest Colorado, DHS Drilling Company Rig #5
is in the process of moving to the Vega Unit (WI of 100%) and is expected to
begin drilling by August 1, 2005.  Permits have been received for
17 locations, thus providing the Company with an eight to twelve month
drilling inventory.  Additional locations are being permitted, and depending
on pipeline capacity, a second rig may move into the field by calendar year
end.  The principal producing zones in the Vega Unit are the Williams Fork
sands of the Mesaverde Formation.  These wells will average approximately
8,200 feet in depth and can typically be drilled and cased within 17 days.
Since the majority of the wells will be directionally drilled from central
production pads, it will be necessary to drill up to four wells before
completion activity can begin.  This will cause numerous wells to be connected
to the sales pipeline concurrently, with a lag time between drilling and
completion efforts. 
Eastern D-J Basin: 
In the eastern DJ Basin (in general 100% WI), Delta is currently
interpreting a Phase II seismic survey that covers approximately 30,000 acres.
Current net production approximates 3.1 Mmcfe per day in the area.  The two
most recent wells that were drilled since a revision of the Company's geologic
model appear to meet or exceed production and reserve expectations.  A
drilling rig should move into the area in September 2005 to initiate
additional drilling activity. 
Columbia River Basin: 
In the Columbia River Basin (Washington State), DHS Drilling Company
recently contracted to provide DHS Rig #7 to another operator to begin
drilling in the basin.  Delta owns a 14.25% After Project Payout Working
Interest under the initial drilling activity.  In addition, Delta has
continued to acquire leasehold and currently has approximately 175,000 net
acres under lease. 
DIVESTITURES 
As part of the Company's ongoing effort to rationalize its property
portfolio, Delta is moving forward to divest non-core assets.  A Letter of
Intent (LOI) for the sale of the Deerlick Creek Field (Delta WI of 100%; net
production of 2.8 Mmcfe per day) in Tuscaloosa County, Alabama has been
signed.  This sale is expected to close in September 2005 with an effective
date of July 1, 2005. 
The Company has executed a LOI for the sale of its Frisco Field properties
(WI ranges from 79% to 96%) in Point Coupee Parish, LA, where net production
approximates 1.5 Mmcfe per day.  The sale is expected to close in August 2005. 
Delta has contracted with a third party oil and gas property auction
company to sell numerous minor properties in which the Company owns small
non-operated working interests.  These properties contribute approximately
1.1 Mmcfe per day in net production and are scheduled to be auctioned during
September 2005. 
On July 20, 2005, Delta sold 250,000 shares of common stock in Tipperary
Corporation.  The Company owns no additional Tipperary Corporation shares. 
The Company is reviewing the potential sale of other non-core assets as
well. 
UPCOMING ANALYST CONFERENCE 
As previously announced, Delta will host an analyst conference on Thursday
August 11, 2005 in Denver, Colorado.  Interested parties may register to
attend the conference on the Company's website (www.deltapetro.com).  Because
space may be limited, interested parties are encouraged to register early.  No
registrations will be accepted after 12 noon (Mountain Time) on August 4,
2005. 
Delta Petroleum Corporation is an oil and gas exploration and development
company based in Denver, Colorado.  The Company's core areas of operations are
the Gulf Coast and Rocky Mountain Regions, which comprise the majority of its
proved reserves, production and long term growth prospects.  Its common stock
is traded on NASDAQ under the symbol "DPTR" and on the Frankfurt Stock
Exchange under the symbol "DPE." 
Forward-looking statements in this announcement are made pursuant to the
safe harbor provisions of the Private Securities Litigation Reform Act of
1995.  Investors are cautioned that all forward-looking statements involve
risks and uncertainty, including without limitation, the costs of exploring
and developing new oil and natural gas reserves, the price for which such
reserves can be sold, environmental concerns effecting the drilling of oil and
natural gas wells, as well as general market conditions, competition and
pricing.  Please refer to the Company's Securities and Exchange Commission
filings for additional information. 
 * CAUTIONARY NOTE TO U.S. INVESTORS - The United States Securities and
Exchange Commission permits oil and gas companies, in their filings with the
SEC, to disclose only proved reserves that a company has demonstrated by
actual production or conclusive formation tests to be economically and legally
producible under existing economic and operating conditions.  In this press
release the terms "estimated ultimate recovery (EUR)" and "probable reserves"
are used.  SEC guidelines strictly prohibit publicly traded companies from
including reserves other than proved reserves in their filings with the SEC.
U.S. investors are urged to consider closely the disclosures in Delta
Petroleum's Form 10-K for the fiscal year ended June 30, 2004. 
For further information contact the Company at (303) 293-9133 or via email at 
                         info@deltapetro.com 
                                  OR
 RJ Falkner & Company, Inc., Investor Relations Counsel at (800) 377-9893 or 
                   via email at info@rjfalkner.com 

SOURCE  Delta Petroleum Corporation 
CONTACT:
Delta Petroleum Corporation, +1-303-293-9133, info@deltapetro.com; or RJ 
Falkner & Company, Inc., Investor Relations Counsel, +1-800-377-9893, 
info@rjfalkner.com, for Delta Petroleum Corporation
-0- Jul/25/2005 17:44 GMT
 
 
Press spacebar to pause and continue. Press esc to stop.