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KU TORP Technology Transfer 3-Day Summer Workshop on 25-Jun-13 8:00 AM

Tue, 25 Jun 2013 13:00:00 GMT

KU TORP Technology Transfer 3-Day Summer Workshop
Start Date: 25-Jun-13 8:00 AM
End Time: 26-Jun-13 5:00 PM
Location: Hyatt Regency Wichita, Wichita, Kansas 67202
Event Details:

Reservoir Characterization Essentials and Waterflood Design

PLUS DAY THREE BONUS ONSHORE PRODUCTION CONFERENCE

18 hours Instruction

You are not going to want to miss this special event KU TORP in association with the Petroleum Technology Transfer Council (PTTC) and the Research Partnership to Secure Energy for America (RPSEA) come together to bring you three packed days of technical contend designed specifically for operators working in the midcontinent region.

Day one will begin with Reservoir Characterization Essentials and highlight the use of geologic and engineering data model and analyze oil an gas reservoirs in the region. Day two will focus on Waterflood Design and will include information on the selection of candidate wells and elements of a good waterflood design.

Finally in a special partnership with RPSEA participants will receive a third day of technical content for no additional charge. Day three will highlight onshore production from leading researchers participating in RPSEA’s small producer program. Technical topics will include, Produced Water Handling, Enhanced Oil Recovery and Production Enhancement.

RPSEA will host a reception on the second day – immediately following the last speaker.

We are currently developing this workshop but save the date now and plan to attend.

Hyatt Regency Wichita

400 West Waterman

Wichita, Kansas 67202

RPSEA Reception on 26-Jun-13 6:00 PM

Wed, 26 Jun 2013 23:00:00 GMT

RPSEA Reception
Start Date: 26-Jun-13 6:00 PM
End Time: 26-Jun-13 8:00 PM
Location: Hyatt Regency Wichita, Wichita, Kansas 67202
Event Details:

RPSEA will host a reception on the second day of the KU TORP Technology Transfer 3-Day Summer Workshop.

The reception will immediately follow the last speaker.
All registrants of the KU TORP Technology Transfer 3-Day Summer Workshop are welcome to attend.

This is not a RPSEA only event.

Hyatt Regency Wichita

400 West Waterman

Wichita, Kansas 67202

RPSEA Onshore Production Conference in Association with KU TORP on 27-Jun-13 8:00 AM

Thu, 27 Jun 2013 13:00:00 GMT

RPSEA Onshore Production Conference in Association with KU TORP
Start Date: 27-Jun-13 8:00 AM
End Time: 27-Jun-13 5:00 PM
Location: Hyatt Regency Wichita, Wichita, Kansas 67202
Event Details:

Day 3 of the KU TORP Technology Transfer 3-Day Summer Workshop.

Day three will highlight onshore production from leading researchers participating in RPSEA’s small producer program. Technical topics will include, Produced Water Handling, Enhanced Oil Recovery and Production Enhancement.

Agenda

Hyatt Regency Wichita

400 West Waterman

Wichita, Kansas 67202

RPSEA Onshore Production Conference: Technological Keys to Enhance Production Operations on 25-Sep-13 8:00 AM

Wed, 25 Sep 2013 13:00:00 GMT

RPSEA Onshore Production Conference: Technological Keys to Enhance Production Operations
Start Date: 25-Sep-13 8:00 AM
End Time: 25-Sep-13 5:00 PM
Location: The Bureau of Economic Geology’s Houston Research Center, Houston, TX 77041
Event Details:

The Onshore Production Conference is just around the corner and we hope that you are planning to join us on September 25th, at The Bureau of Economic Geology’s Houston Research Center.

Come learn the latest perspectives and benefits on what’s being developed in:

• Water Treatment

• Improving Oil Production and Recovery

• Reducing Operating Costs

Registration is required for this event. The registration fee is $50.00.

RPSEA has an active research program with a current portfolio of projects all targeting technology that will benefit the onshore producing community. This conference offers an ideal opportunity to hear the latest perspectives and exchange ideas with industry experts.

Don’t miss this great networking opportunity.

Agenda forthcoming

The Bureau of Economic Geology’s Houston Research Center

11611 West Little York Rd.

Houston, TX 77041

Gulf of Mexico will be strongest offshore market, analysts say

Simone Sebastian - noemail@rpsea.org — Wed, 02 Jan 2013 15:30:00 GMT

The deepwater Gulf of Mexico is poised for a strong comeback, with the number of floating rigs growing from about 36 today to 60 in 2015, analysts at the International Strategy and Investment Group forecast.

In its recently released report, “U.S. Gulf of Mexico Deepwater Outlook: Rising Up From the Ashes,” the investment firm projects that companies will drill about 70 development wells in 2015, triple the number drilled this year and the highest level since 2002. The activity surge would mark a rapid rebound from the catastrophic rig explosion and oil spill at BP’s Macondo well in 2010, which temporarily crippled drilling activity in the region.

“After essentially being left for dead following the devastating Macondo blow out, we believe the deepwater Gulf of Mexico is in the early stages of an extended growth cycle and is poised to be the strongest offshore market in the world through 2015,” the ISI researchers wrote.

Following the oil spill, the total number of rigs in the Gulf of Mexico plummeted from 55 to 12 in just two months. The total rig count has since rebounded to about 48, according to the Baker Hughes rig count.

The ISI report notes that the development of major deepwater projects in the Gulf have led the early resurgence, including Anadarko’s Lucius and Chevron’s Big Foot and Jack/St Malo projects.

To view the actual article on FuelFix.com's website, click GOM.

2-Jan-13 9:30 AM

Total Bids of $157MM Seen for Western Gulf Sale 229

Karen Boman - noemail@rpsea.org — Wed, 28 Nov 2012 19:00:00 GMT

Wednesday's Western Gulf of Mexico Lease Sale 229 garnered high bids of $133.8 million and total bids of approximately $157 million.

Bureau of Ocean Energy Management (BOEM) officials said the sale, the third offshore sale in the U.S. Gulf of Mexico over the past year and the second in the Western Gulf, reflect more than $2 billion of investment by the energy industry in the Gulf of Mexico and indicates "how central the Gulf is to the U.S. energy portfolio" and one of the bedrocks to the nation's all-of-the-above energy portfolio.

Thirteen companies submitted 131 bids on 116 blocks. Chevron Corp. subsidiary Chevron USA submitted the highest bid for a block in the sale, with a $17.2 million bid for East Breaks Block 546.

The sale results did not come as a surprise to John Rodi, Gulf of Mexico regional director for BOEM. Last year's sale was robust in comparison due to the fact that last year's sale was the first in more than two years following the Deepwater Horizon incident.

"The sale results were in the range of what we might expect for a western Gulf sale," Rodi said Wednesday in a conference call with reporters.

The sale results also reflect the industry's significant interest and investment in the deepwater Gulf, Rodi said. The significant potential seen in seismic data in terms of subsalt prompted interest among operators in the East Breaks and Keathley Canyon areas, Rodi said.

BP did not bid on any blocks in the lease sale; BOEM Director Tommy Beaudreau said it did not know BP had not submitted any bids until the bids were opened Wednesday. However, BOEM would not have been able to accept any bids from BP until BP and the U.S. Environmental Protection Agency (EPA) work through an administrative agreement with BP, Beaudreau commented during the conference call Wednesday.

EPA announced Wednesday that it was temporarily suspending BP from entering into new contracts with the Obama administration due to BP's "lack of business integrity" in relation to the Deepwater Horizon oil spill and response. The EPA's voluntary suspension would only apply to new leases, not to BP's existing leases in the Gulf.

However, Beaudreau said he believes BP is "genuine and sincere" in reforming the way it does business. "Our experience with BP is that, following the spill, BP has gone through significant internal reforms," Beaudreau commented. He added that the company is making real changes, not only in its practices but in its culture.

BP has made a number of commitments to the U.S. Department of the Interior in the form of voluntary undertakings. On the basis of these undertakings and other reforms, BOEM has allowed BP to resume operations in the Gulf in the past year, Beaudreau said.

While BP has made significant progress in its commitment to safety and performance, "We need to see continued vigilance on safety and commitment to performing responsible work," Beaudreau said, not just from BP but from all operators in the Gulf.

The commitment to safety not only applies to offshore drilling, but workplace safety in general, said Beaudreau of the recent fire on a platform operated in the Gulf by Black Elk Energy. Beaudreau said BOEM has informed Black Elk it must step up its workplace safety efforts or face more consequences.

BOEM also received at least one bid within the three-statute mile boundary area north of the continental shelf boundary between the United States and Mexico. Any bids submitted on blocks in the area will not be opened until on or before 30 days following approval by U.S. Congress of the agreement between the U.S. and Mexico or May 31, 2013.

At that time, the U.S. Secretary of the Interior may determine whether it is in the best interest of the United States either to open any such bids or to return the bid unopened, BOEM said in a statement.

BOEM estimates the sale could result in the production of 116 to 200 million barrels of oil and 538 to 938 Billion cubic feet of natural gas. BOEM also recently announced that the next Central Gulf lease sale will take place on March 20, 2013. Lease Sale 227 will make 38 million acres available offshore Louisiana, Mississippi and Alabama.

While BOEM officials praised the sale, GHS Research reported Wednesday that it expected the sale to be the worst in decades given the lack of participants and number of blocks offered.

According to GHS' records, the number of companies submitting bids, 13, was the lowest versus the 20 companies that submitted bids in the 2011 Western Gulf lease sale and an average of 42 over the prior 10 sales.

GHS also pointed out that only 3 percent, or 116 blocks, out of 3,873 blocks made available received bids. This level of bidding is the lowest level of interest seen since the 1992 sale, when approximately 1.4 percent of blocks available received bids, and down from last year's approximate 4.9 percent and 7.9 percent average over the prior 10 sales.

Ninety-one percent of the 116 tracts receiving bids lie in deepwater, while 9 percent are on the shelf. This breakdown is in line with the most recent sale split of 93 percent and seven percent, but a higher proportion devoted to deepwater versus shelf than the prior 10 sales, which had a 70 percent and 30 percent split.

The 131 bids received is also the lowest seen since the 1992 sale, when 81 bids were received, and down from the 241 bids made in the 2011 sale and an average of 378 over the prior 10 sales.

While Western Gulf sales tend to attract less interest and money exposed than central Gulf of Mexico lease sales, the preliminary stats indicate there was just minimal interest in this exercise, likely due to just 141 new blocks being offered versus the 626 offered in last year's western Gulf sale.

EPA's decided to temporarily suspend BP from securing new federal government contracts, grants or other covered transactions "until the company can provide sufficient evidence to EPA demonstrating that it meets Federal business standards," EPA said Wednesday in a statement.

The decision reflects BP's Nov. 15 agreement to plead guilty to 11 counts, including misconduct or neglect of ship officers, related to the Deepwater Horizon spill. Other charges include one count of Obstruction of Congress, one misdemeanor count of a violation of the Clean Water Act, and one misdemeanor count of a violation of the Migratory Bird Treaty Act.

The suspension does not affect existing agreements BP may have with the government.

To view the actual article on RIGZONE's website, click Gulf.

28-Nov-12 1:00 PM

U.S. Natural Gas Exports Poised For Takeoff

Peter Kelly-Detwiler - noemail@rpsea.org — Fri, 09 Nov 2012 21:00:00 GMT

Shale gas is the energy topic of the day. Production is increasing, but so is gas demand – for electric generation, transportation, and as an industrial feedstock. However, perhaps the most significant dynamic with the potential to drive natural gas prices up in the foreseeable future is a growing push to export LNG from the US. That particular dynamic has recently gone into hyper-drive, with numerous liquid natural gas (LNG) export requests having been filed with the US Department of Energy in the past few years.

Consider this: according to the Energy Information Administration, total natural gas consumption for 2011 was 24.3 trillion cubic feet (Tcf), and 2012 consumption looks to be on the order of 26 Tcf. In the meantime, just since mid-August, US companies have filed for permits with the USDOE to export 7.8 Tcf of LNG – about 30% of current total domestic consumption. Total requests year-to- date equal 11.2 Tcf (though almost 1 Tcf is for re-export of Canadian gas). Add to that, the 5.3 Tcf of exports requested last year, and you get approximately 16.5 Tcf. That’s over 60% of current domestic consumption. It’s also more than the amount of US LNG export capacity from five brownfield and three Greenfield projects in play that are listed in a recent Wood MacKenzie report.

Of course, not all of these planned facilities will get permitted or built. But some will, and perhaps a good number, because the economics are compelling and the market is there.

At the September LNG Producer-Consumer Conference in Tokyo, the Indian delegate was quoted as saying that India’s LNG import capability will multiply five-fold in as many years. It’s not likely to stop there, in a country of over a billion inhabitants, with their enormous energy problems. For its part, post-Fukushima Japan has shut down all but 2 of its 54 reactors, and Tokyo Electric Poweris reportedly in talks with North American suppliers(and negotiating with Washington) to secure long-range gas contracts to supply gas-fired generators. There is a big hole to fill and gas will help fill it.

Clearly, much of the LNG imported by these and other Asian countries will be sourced from places other than North America. Today, 18 countries export the gas to 25 importing nations (with Qatar supplying almost a third of all global LNG in 2011). The US is the new kid on the block, supplying only .1% of the world’s exports last year. However, a powerful combination of robust pipelines, multiple vendors, and world class shale reserves is likely to turn the US – and especially the Gulf Coast – into a favored supplier. If permits can be secured, export growth could occur relatively quickly.

The process of condensing natural gas into a liquid at -160 degrees Celsius reduces its volume by a factor 600, and makes it economic to ship. But the industry is enormously capital-intensive and costs are considerable: A “typical” investment includes an outlay of one to two billion dollars for liquefaction facilities, over two hundred million per vessel for LNG tankers, and half a billion to a billion dollars for receiving terminals. Yet even with those costs, the economic incentive is there. Currently, the North America pays just over $3 per mmBtu, while the Japanese spot market price hovers around $13. In part that’s because Asian gas prices are linked to oil. According to Reuters, long-term contract shipments to Japan would likely be priced at less than $10 per mmBtu. That’s a powerful market differential. Investments in supplying LNG to hungry Asian markets may yield payback periods of under five years for the first players into the game, Woods MacKenzie notes.

The laws of economics dictate that, in the long run, supply and demand reach an equilibrium. LNG facilitates that equilibrium dynamic by linking land-locked North American supplies to world markets. The arbitrage opportunity may eventually diminish if Asian gas and oil prices are de-linked (gas is currently indexed to oil, but there is a strong movement to change that). In the meantime, however, that price differential constitutes a powerful incentive.

The Obama Administration has been looking at this LNG export issue, with a study and recommendations (thrice delayed) due to be released in December. To some degree, this push for numerous twenty-year (or longer) export permits seems to have caught just about everybody off guard. In fact, the Energy Information Administration study from January of this year evaluating this issue posits a high case scenario of 12 Bcf/day. In the meantime, exporters have lined up quickly, and export requests for 1.25 times that amount have been submitted in the past two years.

Although it can take several years and billions of dollars to build the LNG facilities, the LNG price differential and export dynamic truly make gas markets more “liquid.” This is bound to have a long-term upward impact on US natural gas prices. The challenge for the Obama Administration will be how to balance international free markets with the long-sought goal of US energy security. It won’t be easy.

To view the actual article on Forbes website, click natural gas.

9-Nov-12 3:00 PM

U.S. May Soon Become World’s Top Oil Producer

Wed, 24 Oct 2012 17:00:00 GMT

U.S. oil output is surging so fast that the United States could soon overtake Saudi Arabia as the world’s biggest producer.

Driven by high prices and new drilling methods, U.S. production of crude and other liquid hydrocarbons is on track to rise 7 percent this year to an average of 10.9 million barrels per day. This will be the fourth straight year of crude increases and the biggest single-year gain since 1951.

The boom has surprised even the experts.

“Five years ago, if I or anyone had predicted today’s production growth, people would have thought we were crazy,” says Jim Burkhard, head of oil markets research at IHS CERA, an energy consulting firm.

The Energy Department forecasts that U.S. production of crude and other liquid hydrocarbons, which includes biofuels, will average 11.4 million barrels per day next year. That would be a record for the U.S. and just below Saudi Arabia’s output of 11.6 million barrels. Citibank forecasts U.S. production could reach 13 million to 15 million barrels per day by 2020, helping to make North America “the new Middle East.”

The last year the U.S. was the world’s largest producer was 2002, after the Saudis drastically cut production because of low oil prices in the aftermath of 9/11. Since then, the Saudis and the Russians have been the world leaders.

The United States will still need to import lots of oil in the years ahead. Americans use 18.7 million barrels per day. But thanks to the growth in domestic production and the improving fuel efficiency of the nation’s cars and trucks, imports could fall by half by the end of the decade.

The increase in production hasn’t translated to cheaper gasoline at the pump, and prices are expected to stay relatively high for the next few years because of growing demand for oil in developing nations and political instability in the Middle East and North Africa.

Still, producing more oil domestically, and importing less, gives the economy a significant boost.

The companies profiting range from independent drillers to large international oil companies such as Royal Dutch Shell, which increasingly see the U.S. as one of the most promising places to drill. ExxonMobil agreed last month to spend $1.6 billion to increase its U.S. oil holdings.

Increased drilling is driving economic growth in states such as North Dakota, Oklahoma, Wyoming, Montana and Texas, all of which have unemployment rates far below the national average of 7.8 percent. North Dakota is at 3 percent; Oklahoma, 5.2.

Businesses that serve the oil industry, such as steel companies that supply drilling pipe and railroads that transport oil, aren’t the only ones benefiting. Homebuilders, auto dealers and retailers in energy-producing states are also getting a lift.

IHS says the oil and gas drilling boom, which already supports 1.7 million jobs, will lead to the creation of 1.3 million jobs across the U.S. economy by the end of the decade.

“It’s the most important change to the economy since the advent of personal computers pushed up productivity in the 1990s,” says economist Philip Verleger, a visiting fellow at the Peterson Institute of International Economics.

The major factor driving domestic production higher is a newfound ability to squeeze oil out of rock once thought too difficult and expensive to tap. Drillers have learned to drill horizontally into long, thin seams of shale and other rock that holds oil, instead of searching for rare underground pools of hydrocarbons that have accumulated over millions of years.

To free the oil and gas from the rock, drillers crack it open by pumping water, sand and chemicals into the ground at high pressure, a process is known as hydraulic fracturing, or “fracking.”

While expanded use of the method has unlocked enormous reserves of oil and gas, it has also raised concerns that contaminated water produced in the process could leak into drinking water.

The surge in oil production has other roots, as well:

— A long period of high oil prices has given drillers the cash and the motivation to spend the large sums required to develop new techniques and search new places for oil. Over the past decade, oil has averaged $69 a barrel. During the previous decade, it averaged $21.

— Production in the Gulf of Mexico, which slowed after BP’s 2010 well disaster and oil spill, has begun to climb again. Huge recent finds there are expected to help growth continue.

— A natural gas glut forced drillers to dramatically slow natural gas exploration beginning about a year ago. Drillers suddenly had plenty of equipment and workers to shift to oil.

The most prolific of the new shale formations are in North Dakota and Texas. Activity is also rising in Oklahoma, Colorado, Ohio and other states.

Production from shale formations is expected to grow from 1.6 million barrels per day this year to 4.2 million barrels per day by 2020, according to Wood Mackenzie, an energy consulting firm. That means these new formations will yield more oil by 2020 than major oil suppliers such as Iran and Canada produce today.

U.S. oil and liquids production reached a peak of 11.2 million barrels per day in 1985, when Alaskan fields were producing enormous amounts of crude, then began a long decline. From 1986 through 2008, crude production fell every year but one, dropping by 44 percent over that period. The United States imported nearly 60 percent of the oil it burned in 2006.

By the end of this year, U.S. crude output will be at its highest level since 1998 and oil imports will be lower than at any time since 1992, at 41 percent of consumption.

“It’s a stunning turnaround,” Burkhard says.

Whether the U.S. supplants Saudi Arabia as the world’s biggest producer will depend on the price of oil and Saudi production in the years ahead. Saudi Arabia sits on the world’s largest reserves of oil, and it raises and lowers production to try to keep oil prices steady. Saudi output is expected to remain about flat between now and 2017, according to the International Energy Agency.

But Saudi oil is cheap to tap, while the methods needed to tap U.S. oil are very expensive. If the price of oil falls below $75 per barrel, drillers in the U.S. will almost certainly begin to cut back.

The International Energy Agency forecasts that global oil prices, which have averaged $107 per barrel this year, will slip to an average of $89 over the next five years — not a big enough drop to lead companies to cut back on exploration deeply.

Nor are they expected to fall enough to bring back the days of cheap gasoline. Still, more of the money that Americans spend at filling stations will flow to domestic drillers, which are then more likely to buy equipment here and hire more U.S. workers.

“Drivers will have to pay high prices, sure, but at least they’ll have a job,” Verleger says.

To view the actual article on Fuel Fix's website, click oil.

24-Oct-12 12:00 PM

Deepwater GOM Rig Count to Pass Pre-Moratorium Levels by Year-End

Karen Bowman - noemail@rpsea.org — Thu, 13 Sep 2012 16:00:00 GMT

The Gulf of Mexico deepwater rig count should surpass pre-moratorium levels by the end of 2012 and reach 45 to 50 rigs by 2014, according to Barclays Capital's September 2012 drilling permit report.

The Bureau of Ocean Energy Management (BOEM) last month issued 25 total permits for floating rigs, down from 27 permits announced in July and compared to 37 permits in June. The 25 permits issued include 21 exploratory permits and four permits for development jobs.

Three new well permits were issued in August, down four from July, and 19 revised new well permits were issued, Barclays reported.

"Despite the dip in permits issued in August, we believe permit activity in the U.S. Gulf of Mexico remains healthy and suggest a continued improvement in the permitting process, which was stifled following the moratorium, and indicates the floating rig count is set to increase further as more deepwater rigs migrate to the region," Barclays analysts noted.

Two the permits issued last month were issued for the ultra-deepwater Gulf, both for Shell with the Noble Danny Adkins (UDW semisub), Barclays reported.

BOEM permit announcements tend to lag contract awards for the offshore drillers typically by a couple of weeks, Barclays analysts noted. However, offshore permit issuances are one of the final steps prior to the start of drilling, and help indicate future offshore activity levels.

Ultra-deepwater drilling activity has picked up worldwide, including areas outside the deepwater 'Golden Triangle' of the U.S. Gulf, Brazil, and West Africa. As a result, drilling contractors such as Transocean are seeking growing demand for ultra-deepwater drilling rigs.

The non-binding letter of intents entered by drilling contractor Transocean for four ultra-deepwater drillships will strengthen Transocean's ties with a best-in-class major, which Barclays believes to be Shell, and moves the company up the technology curve with state-of-the-art assets, according to a Barclays Sept. 13 analyst note.

The units are not arctic class, said Barclays analysts, who believe Shell could intend for the rigs to initially work in the U.S. Gulf.

"Due to Transocean's international domiciling, we believe there is scope for a tax rate significantly lower than the company's corporate tax rate in the event the rigs work in the U.S. Gulf of Mexico," Barclays analysts reported. That tax rate could be as low as the mid-single digits, in line with Rowan's tax rate expectations for drillships working in the U.S. Gulf.

To view the actual article, click Rigzone.com.

13-Sep-12 11:00 AM

USGS Releases U.S. Oil & Gas Reserve Growth Estimate

Mon, 20 Aug 2012 16:00:00 GMT

The U.S. Geological Survey (USGS) released on Tuesday, August 14, a new estimate for potential additions to domestic oil and gas reserves from reserve growth in discovered, conventional accumulations in the United States. The USGS estimates that the mean potential undiscovered, conventional reserve additions for the United States total 32 billion barrels (bb) of oil, 291 trillion cubic feet (tcf) of natural gas, and 10 bb of natural gas liquids, constituting about 10 percent of the overall U.S. oil and gas endowment.

“As part of the Obama Administration’s all-of-the-above energy strategy, we are taking aggressive steps to safely and responsibly expand domestic energy production,” said Interior Secretary Ken Salazar. “USGS’s ongoing work to identify and estimate U.S. energy supplies – and to make that information available to everyone - is fundamental to our efforts to continue to grow America’s energy economy.”

The U.S. estimates released today are for technically recoverable oil and gas, and do not include reserve growth estimates for Federal offshore areas. These estimates were made using a new assessment methodology developed by the USGS.

Reserve growth is the increase in estimated volumes of oil and natural gas that can be recovered from discovered (known) fields and reservoirs through time. Most reserve growth results from delineation of new reservoirs, field extensions, or improved recovery techniques, thereby enhancing efficiency, and recalculation of reserves due to changing economic and operating conditions.

"By providing geologically based, domestically consistent estimates of the potential additions of oil and gas from the growth in reserves in known fields, and placing that information in the public domain, we are furnishing a valuable projection on how much and where fossil fuels may be produced in the future," said USGS Director Marcia McNutt. "When combined with our estimates of undiscovered resources, policy makers can obtain a more complete picture of domestic, technically recoverable oil and gas."

These volumes represent an estimate of the potential future growth of current U.S. reserve estimates over time based on current technologies, and greater understanding of current reservoirs, among other advances. For comparison, the current mean USGS estimates for undiscovered, technically recoverable conventional oil and gas resources from onshore and underlying State waters are 27 bb of oil and 388 tcf of natural gas, respectively.

Reserve growth is a component of the overall oil and gas endowment, but is distinct from reserves and from undiscovered, technically recoverable resources – all three important but separate measurements used in efforts by industry and government to make energy decisions based on the best available science.

Unlike past estimates of reserve growth that relied on statistical extrapolations of growth trends, the new USGS assessment is based on detailed analysis of geology and engineering practices used in producing fields. The assessment uses both published and commercial sources of geologic information and field-production data.

Region	Mean Barrels of Crude Oil	Mean Cubic Feet of Natural Gas	Mean Barrels of Natural Gas Liquid
1. Alaska/Pacific Region	20bb	32tcf	1bb
2. Colorado Plateau/Basin & Range	2bb	18tcf	1bb
3. West Texas/Eastern New Mexico	4bb	52tcf	3bb
4. Gulf Coast	3bb	144tcf	4bb
5. Midcontinent/Eastern Region	2bb	45tcf	1bb
Totals	32bb	291tcf	10bb

Continuous, or unconventional, oil and gas accumulations, such as shale gas, tight gas, and tight oil were removed from the data set for this study. No attempt was made to estimate the economic viability of the recoverable oil and gas as part of these future projections.

“Today’s estimates are more good news for U.S. energy security, and affirm the need for the all-of-the above energy strategy that the President has implemented,” said Salazar, noting that U.S. dependence on foreign oil has gone down every year during the Obama Administration, including a reduction in net oil imports by ten percent – or one million barrels a day – in the last year alone. Total oil production from federal lands and waters has increased 13 percent during the first three years of this Administration, compared to the last three years of the previous Administration. Oil production in the first quarter of 2012 was higher than any time in the last 14 years and natural gas production is at its highest level ever.

Estimates of reserve growth for the world, excluding the United States, were released in June 2012 and total 665 bb of oil, 1,429 tcf of natural gas, and 16 bb of natural gas liquids.

To view the actual article on offshoresource.com, click USGS.

20-Aug-12 11:00 AM

US Chamber official makes case for shale energy in WV

Taylor Kuykendall - noemail@rpsea.org — Wed, 25 Jul 2012 15:00:00 GMT

The world's largest business federation is throwing its weight behind shale gas, and one of its officials took the time to celebrate new "Shale Works for US" campaign in West Virginia on July 24.

Karen Harbert, president and CEO of the Institute for 21st Century Energy of the U.S. Chamber of Commerce, said the Shale Works for US campaign educates the public about the burgeoning industry. The campaign, promoted at a news conference and other media events July 24, aims to promote the mission of building support "for the vast economic and energy security benefits of natural gas and oil produced from shale."

"West Virginia has a long history of providing its natural energy resources to the rest of the country," Harbert said. "Now the opportunity exists for West Virginia to build upon the strong coal industry by becoming a leader in shale energy production."

Educating the public

The primary goal, Harbert said in an interview after the press conference, is to get information out there. Right now, she said, the shale gas industry is still in the early stages of introducing itself to the public.

"It's a grassroots campaign intended to bring light and illuminate the businesses that are benefiting directly and indirectly from shale development," Harbert said. "It's not only the industry, it's the hotels, the restaurants, the service companies, the Caterpillar dealer that are benefiting from this and generating new economic activity."

The natural gas industry, she said, is allowing people to stay in places where other industry has already moved out.

"This is affording a whole new breath of life into these communities," she said. "People can stay in these communities where they want to stay. They have jobs where they can stay and their kids can stay."

The institute's effort is to ensure that the path for shale energy industry is clear of any unnecessary obstruction.

"We've got to have the right policies and the right regulatory framework," Harbert said. " … We want to make sure that we approach this with all of the facts on the table and get the right outcome."

What's at stake, Harbert said, is an industry that has changed "the whole landscape" of energy and has potential to be a "gamechanger for the economy" in the U.S.

"Our economy is desperately in need of jobs, revenue and investment. Here is something that is right underneath or feet," Harbert said. "It's been given to us. Let's not blow it."

Let states determine role

A potential obstacle, Harbert said, could end up being federal regulations that she said aren't as well-suited to needs as those by state-level agencies.

"We are seeing a significant increase … a regulatory tsunami coming at energy resources of many forms and as it relates to things that we can address through legislation. We're certainly advocating legislation, but legislation isn't moving at the federal level," Harbert said. "On the regulatory side of things, we are very active."

She said the U.S. Chamber is actively trying to reduce any impediments to the growth of the shale industry. The states, she said, have the ability to introduce regulations tailored to specific energy developments.

"It has appropriately been left to the states for many, many years - decades. It's always been in the hands of state regulators," Harbert said. "They've done a pretty good job. The closer you are to a resource, the better the regulator you are. We think that's the way it should remain."

However, a number of federal agencies have wanted to get in on regulating shale gas development in one way or another. Harbert warns that too many federal agencies, without some sort of streamlining of the process, could smother the industry.

"Let's not make it one size fits all that will jeopardize the economic activity," she said. "The more we add additional layers of regulation and permits, it gets very expensive."

While Harbert mostly encouraged state-level development of shale gas law, she said there is room for some consistency in industry rules. In places such as the Marcellus shale region, gas plays aren't bound by state borders, and operators may work under different rules.

"Harmonization of certain standards over time, I think, will make sense," Harbert said. "I think it best comes from industry showing what is the best practices, what is the best they can do and then be expected to live up to that."

The discovery of a new way of extracting gas, Harbert said, shouldn't cause a reflexive move toward simply piling on regulations. She said a close look at where current regulation falls short should be undertaken with serious consideration to preserving the economic viability of natural gas.

"We shouldn't just being going for new regulations because there's new opportunity," she said. "What is really needed? Where is the state function not adequate?"

All energy is on the table

All of this support of natural gas, she added, does not mean American industry or people should turn their backs on the coal industry.

"It is absolutely not one or the other," Harbert said. "This is not picking winners or losers. If you look at the demand for the energy in the United States … it's going up. We're going to need all forms of energy. We're going to need oil, gas, coal, nuclear and renewables. We don't have the luxury picking and choosing, nor should we."

She said renewables have a role to play, but "we have to be realistic how much they can contribute and in what time frame and what cost."

"We believe (coal) has provided us a huge economic advantage," Harbert said. It's provided affordable electricity for so long, we shouldn't be writing it off."

Affordable electricity – one of the biggest challenges the renewable energy has thus far struggled to solve – is easily provided by gas and coal.

"If we don't have affordable energy, we're not going to attract the manufacturing industry, we're not going to get the chemical industry back, we're not going to attract any of the things that we know we need to get our economy on its feet," Harbert said. "Coal has a big part to play in that. Any policy that cherrypicks is wrong."

Harbert said the battle the Chamber is fighting for coal is "very different" than the battle for natural gas. With the coal fight, she said, "the gloves are off."

"We haven't let up," she said. " … On coal, the sides are well-known. We are on the side of coal needs to exist and we are fighting all the ways we know how to fight – regulatory battles, the litigation."

Challenges for development

While the natural gas industry enjoys considerable popularity among numerous officials, there are still some challenges looming on the horizon.

Access to federal lands, Harbert said, is one of the major concerns of her organization.

"In order for this revolution … to continue, we're going to have to get access to federal lands," she said.

Also erratic legislation, Harbert said, could threaten market stabilities. She cited as an example the tax credit given to the wind energy industry. The credits are up for renewable, prompting many in the wind energy to withdraw investment until Congressional action.

As for environmental concerns, Harbert said, there needs to be an honest and open discussion about the actual impacts of the industry.

"We should have a very transparent debate, but the facts matter on this," Harbert said. "When there are mistakes by the industry, they should correct it and they should be held accountable for it. There are best practices the industry is coming together to put out and they should adhere."

To view the actual article on The State Journal's website, click shale.

25-Jul-12 10:00 AM

Deputy Energy Secretary: Technology key to harnessing natural gas potential

Daniel Poneman - noemail@rpsea.org — Wed, 18 Jul 2012 16:00:00 GMT

The following was written by Deputy Energy Secretary Daniel Poneman. During a visit to Houston last week, Poneman announced the winners of federal grants to develop technology for using natural gas to fuel vehicles.

As a result of the shale gas revolution under way in the United States, more natural gas is being produced in America than at any time in the past. Domestic gas production grew by 7.9 percent last year -– the largest volume increase ever. Indeed, the United States has become the world’s leading natural gas producer.

The natural gas boom in the United States offers a tremendous opportunity to strengthen American energy security by drastically reducing our dependence on imported oil, while at the same time creating new U.S. jobs and industries. This is precisely why President Barack Obama is committed to safely and responsibly harnessing American oil and gas resources, and to developing the technologies that will unlock new domestic energy sources.

For example, we’re looking to find ways to expand the use of natural gas for vehicles.

Last week while I was in Houston attending clean energy events across the city, I announced 13 new cutting-edge research projects — for a total of $30 million — that will pursue innovations in natural gas storage tanks and fueling stations, helping to harness our abundant supplies of domestic natural gas for use in cars and trucks.

The projects were selected by the Department of Energy’s Advanced Research Projects Agency – Energy, which was launched in 2009 to seek out high-risk, breakthrough technologies that have the potential to fundamentally transform how we use and produce energy in America.

Under this new program, the Energy Department will research ways to engineer light-weight, affordable natural gas tanks for vehicles and to develop natural gas compressors that can efficiently fuel a natural gas vehicle at home. These innovations will help put more natural gas vehicles on the road, so that families and businesses nationwide can benefit.

Two of these cutting-edge projects will be taking place in Texas.

Texas A&M University, in College Station, will receive $3 million to develop new, highly adsorbent materials that will enable natural gas to be stored at low pressures but high densities, while the Center for Electromechanics at the University of Texas at Austin will receive $4.3 million to develop an at-home natural gas refueling system that compresses gas with a single piston. Unlike current four-piston compressors, the Center for Electromechanics’ integrated single-piston system will use fewer moving parts, leading to a more reliable, lighter, and cost-effective compressor.

These innovations build on efforts already underway through the Energy Department’s Clean Cities program and the National Clean Fleets Partnership to help large fleet operators in the public and private sector transition to compressed natural gas or liquefied natural gas for long-haul trucks or commercial vehicles. We know that in many of these cases, using natural gas as a transportation fuel already makes economic sense.

The awards we announced in Houston take an important step forward in making natural gas vehicles accessible and affordable for Americans nationwide, so that we can tap into the promise of our domestic energy supply and pave the way for a more secure energy future in the United States.

To view the actual article on Fuel Fix's website, click natural gas.

18-Jul-12 11:00 AM

RPSEA Selects Projects to Award $8.4 Million for the Small Producer Program

Danette Mozisek - noemail@rpsea.org — Wed, 20 Jun 2012 16:00:00 GMT

The Research Partnership to Secure Energy for America (RPSEA) announces nine proposals under the Small Producer Program have been selected for negotiations leading to an award under its contract with the U.S. Department of Energy’s (DOE) National Energy Technology Laboratory and in support of the Ultra-Deepwater and Unconventional Natural Gas and Other Petroleum Resources Research and Development Program that was established by DOE pursuant to the Energy Policy Act of 2005.

The $8.4 million in federal funding is added to $5.7 million in cost share by the industry participants giving a total value of the nine selections of more than $14 million. These 2011 Small Producer Program selections add to the 21 existing projects.

"The 2011 Small Producer Program selections are intended to develop technology that will enable small producing companies to produce domestic oil and gas resources in an environmentally responsible manner, while maximizing recovery from those resources,” RPSEA Vice President, Onshore Programs Kent Perry said. “Ensuring maximum production from our current resources is an important step toward meeting our nation’s energy needs.”

Awards, open to any U.S.-based organization, are negotiated once project selections are made within each RPSEA program - Unconventional Resources, Small Producer and Ultra-Deepwater. These projects focus on improving safety, minimizing environmental impacts, increasing efficiencies and reducing costs of domestic hydrocarbon resources, maximizing their value. Collaboration of America’s leading universities, research institutions, independents, national laboratories, state associations, service and operating companies is encouraged to utilize each of their research and technology resources. Proposals must provide a minimum of 20% cost share with a minimum of 50% for field demonstration projects.

2011 Small Producer Program Selected Projects

Cost-Effective Treatment of Produced Water Using Co-Produced Energy Sources Phase II: Field Scale Demonstration and Commercialization
Project Leader: New Mexico Institute of Mining and Technology

Field Demonstration of Eco-Friendly Creation of Propped Hydraulic Fractures
Project Leader: DaniMer Scientific, LLC

Field Demonstration of Chemical Flooding of the Trembley Oilfield, Reno County, Kansas
Project Leader: The University of Kansas Center for Research

Hybrid Rotor Compression for Multiphase and Liquids-Rich Wellhead Production Applications
Project Leader: OsComp Systems Inc.

Study and Pilot Test of Preformed Particle Gel Conformance Control Combined with Surfactant Treatment
Project Leader: Missouri University of Science and Technology

Basin-Scale Produced Water Management Tools and Options – GIS-Based Models and Statistical Analysis of Shale Gas/Tight Sand Reservoirs and Their Produced Water Streams, Uinta Basin, Utah
Project Leader: Utah Geological Survey

Reduction of Uncertainty in Surfactant-Flooding Pilot Design Using Multiple Single Well Tests, Fingerprinting, and Modeling
Project Leader: The University of Oklahoma

Upstream Ultrasonic Processing for Small Producers: Preventative Maintenance for Paraffin Management in Production Tubing Using Non-Invasive Ultrasonic Technology
Project Leader: Pacific Northwest National Laboratory

Water Management in Mature Oil Fields Using Advanced Particle Gels
Project Leader: The University of Texas at Austin

About RPSEA
RPSEA is a 501(c)(3) nonprofit consortium with more than 180 members, including 22 of the nation's premier research universities, six national laboratories, other major research institutions, large and small energy producers and energy consumers. The mission of RPSEA, headquartered in Sugar Land, Texas, is to provide a stewardship role in ensuring the focused research, development and deployment of safe and environmentally responsible technology that can effectively deliver hydrocarbons from domestic resources to the citizens of the United States. Additional information can be found at www.rpsea.org.

Funding for the projects is provided through the U.S. Department of Energy’s Ultra-Deepwater and Unconventional Natural Gas and Other Petroleum Resources Research and Development Program established pursuant to the Energy Policy Act of 2005. This program—funded from lease bonuses and royalties paid by industry to produce oil and gas on federal lands—is specifically designed to maximize the value of natural gas and other petroleum resources of the United States by increasing the supply of such resources, through reducing the cost and increasing the efficiency of exploration for and production of such resources, while improving safety and minimizing environmental impacts. The Secretary of Energy has ultimate responsibility for and oversight of all aspects of this program. RPSEA is under contract with the U.S. Department of Energy’s National Energy Technology Laboratory to administer three elements of the program.

20-Jun-12 11:00 AM

America’s New Energy Reality

Daniel Yergin - noemail@rpsea.org — Tue, 12 Jun 2012 15:00:00 GMT

AMERICA needs a new political discourse on energy. This would recognize the emerging reality that the United States has turned around as an energy producer and is on a major upswing. And the impact will be measured not just in energy security and the balance of payments. Energy development also turns out to be an engine for job creation and economic growth — something that would hardly have been considered the last time we were electing a president.

In 2008, the rise in oil prices was accompanied — and partly fueled — by a belief that an era of permanent scarcity was at hand. This mentality had deep roots extending back to the 1970s, when the United States went from being a minor importer of oil to a major importer. In the 2008 rendition, falling oil output was considered simply inevitable. The only questions were at what rate petroleum imports would rise and whether that rate would be slowed.

The outlook was much the same for natural gas. Production would inevitably decline, and the country was on the way to spending $100 billion a year to import liquefied natural gas from West Africa, the Middle East, even Australia and Russia. The energy burden on our trade deficit would only increase, adding to our economic distress.

But that is not at all how things are turning out. Technology made the difference. The natural gas market has been transformed by the rapid expansion of shale gas production. A dozen years ago, shale gas amounted to only about 2 percent of United States production. Today, it is 37 percent and rising. Natural gas is in such ample supply that its price has tanked. This unanticipated abundance has ignited a new political argument about liquefied natural gas — not about how much the United States will import but rather how much it should export.

The oil story is also being rewritten. Net petroleum imports have fallen from 60 percent of total consumption in 2005 to 42 percent today. Part of the reason is on the demand side. The improving gasoline efficiency of cars will eventually reduce oil demand by at least a couple of million barrels per day.

The other part is the supply side — the turnaround in United States oil production, which has risen 25 percent since 2008. It could increase by 600,000 barrels per day this year. The biggest part of the increase is coming from what has become the “new thing” in energy — tight oil. That is the term for oil produced from tight rock formations with the same technology used to produce shale gas.

Tight oil is redrawing the map of North American oil. At the beginning of this year, North Dakota overtook California as the nation’s third largest oil-producing state. It didn’t stop there. It just overtook Alaska, to become No. 2 after Texas. Tight oil could reach more than four million barrels per day by 2020.

What really brings home the new reality is a milestone attained last year: In 2011, the United States registered the largest increase in oil production of any country outside of OPEC.

If one takes a broader North American perspective, the changes in the supply picture are even more striking. The output of Canadian oil sands has tripled since 2000 and is now greater than Libya’s output before its civil war began in February 2011.

This adds up to a very different outlook from a few years ago. Until fairly recently, energy independence was a subject to get laughs. The joke was that America was actually becoming more and more dependent upon imports. But now “energy independence” has become a subject of serious discussion and debate.

The prospects for actual energy independence remain elusive. It takes some very heroic assumptions to see that happening. But with oil demand in the United States declining, output rising and increasing integration with Canada, the United States is certainly on the way to becoming “energy less dependent.”

At the same time, Brazil is developing its huge offshore reserves and could become one of the world’s powerhouses in terms of oil production, far overshadowing its impressive output of ethanol.

The results of this hemispheric upsurge will have far-reaching consequences — nothing less than a rebalancing of world oil. Much less oil will come from the Eastern Hemisphere to the Western Hemisphere, and much more Middle Eastern oil will flow to Asia. As it is, China already imports more oil from the Persian Gulf than the United States does.

The impact is becoming evident in the way America talks about energy. President Obama’s address to Congress in February 2009 was all about “clean, renewable energy” and called for doubling “this nation’s supply of renewable energy in the next three years.” His 2010 State of the Union address was about “clean energy jobs.” He had barely a word for oil and natural gas in those speeches.

IN his 2012 address, the president caught up with the new reality and spoke with quite a different emphasis. “This country,” he declared, “needs an all-out, all-of-the-above strategy that develops every available source of energy.” He pointed to the near-doubling of renewable energy use since 2008 and rightly emphasized their importance to the nation’s future energy mix. But this year he devoted almost as much time to natural gas and oil as to renewables. His announcement that “American oil production is the highest it has been in eight years” turned out to be an applause line.

This new discourse is shaped not only by the surge in oil and gas production. But it also represents a growing recognition of what this means for the overall economy. Traditionally, the major arguments in favor of domestic oil and gas production have mainly been about energy security and balance of payments. But now this surge is recognized as an engine of economic growth. Increasing domestic supply means that fewer dollars are going overseas and more of them are staying at home, going into investment and job creation.

Nothing looms larger right now than the employment part. This domestic production comes with long supply chains and creates a lot of jobs along those chains. In his 2012 speech, the president cited a study that found that shale gas development had, by 2010, created 600,000 new jobs. Moreover, these jobs are spread widely across the nation. It is because of jobs that Gov. John Kasich, a Republican, is encouraging the development of the Utica shale in Ohio and Gov. Andrew M. Cuomo, a Democrat, is considering opening economically depressed areas in New York State to shale gas development.

Lower energy costs are also providing a big boost to the revival of manufacturing in the United States and the competitive position of American industries in the global economy. A few years ago, both United States and European petrochemical companies, which use natural gas to make their products, would not have contemplated new investments in the United States. Natural gas was too expensive. Now, with abundant and cheap gas, they are migrating back, bringing billions of dollars of new investment with them — and a lot of new jobs.

According to the old script, United States oil production was too marginal to affect world oil prices. But the gap today between demand and available supply on the world oil market is narrow. The additional oil Saudi Arabia is putting into the market will help replace Iranian exports as they are increasingly squeezed out of the market by sanctions that start later this month. But if America’s increase of 1.6 million barrels per day since 2008 had not occurred, then the world oil market would be even tighter. We would be looking at much higher prices — and voters would be even angrier.

America’s new story for energy is still unfolding. It includes the continuing development and expansion of renewables and increased energy efficiency, both of which will be essential to our future energy mix. But what is striking is this great revival in oil and gas production in the United States, with wide impacts on jobs, economic development and the competitiveness of American industry. This new reality requires a new way of thinking and talking about America’s improving energy position and how to facilitate this growth in an environmentally sound way — recognizing the considerable benefits this will bring in an era of economic uncertainty.

To see the actual article, click NY Times.

12-Jun-12 10:00 AM

Cretaceous Mancos Shale Uinta Basin, Utah: Resource Potential and Best Practices for an Emerging Shale Gas Play (09122-07)

Fri, 14 Jun 2013 15:57:24 GMT

Utah Geological Survey - Principal Investigator: Craig D. Morgan

Objective: The objective of this research is to improve the understanding of the Mancos Shale play in Utah, specifically preferred target intervals and the best drilling, completion, and production strategies.

Period of Performance: October 20, 2010 to October 20, 2013

Abstract

Website

Project Fact Sheet

Current Unconventional Resources Project Website Links

Fri, 14 Jun 2013 15:53:55 GMT

Please note, not all projects have website links. Those that do are listed below for your viewing of the project's progress. Links will be added as they are submitted to RPSEA. target=_blank>An Integrated Framework for the Treatment and Management of Produced Water Comprehensive Investigation of the Biogeochemical Factors Enhancing Microbially Generated Methane in Coalbeds Gas Condensate Productivity in Tight Gas Sands Novel Concepts for Unconventional Gas Development in Shales, Tight Sands and Coalbeds Paleozoic Shale-Gas Resources of the Colorado Plateau and Eastern Great Basin, Utah: Multiple Frontier Exploration Opportunities Application of Natural Gas Composition to Modeling Communication Within and Filling of Large Tight-Gas-Sand Reservoirs, Rocky Mountains Geological Foundation for Production of Natural Gas from Diverse Shale Formations Gas Production Forecasting From Tight-Gas Reservoirs: Integrating Natural Fracture Networks and Hydraulic Fracture...

Research Partnership to Secure Energy for America

Thu, 13 Jun 2013 20:08:24 GMT

Onshore Production Conference in Association with KU TORP June 25-27 RPSEA will host a reception on the second day. Hyatt Regency Wichita Wichita, Kansas Ultra-Deepwater Technology Conference October 29-30 Lone Star Corporate College The Woodlands, TX Requests for Proposals RPSEA is pleased to announce it anticipates releasing the 2012 Requests for Proposals for the Ultra-Deepwater program during the third quarter of 2013. The RFPs will be posted on the Current Request for Proposals page under the Business with RPSEA menu button when they are released. The 2012 RFPs for the Unconventional Resources Program and the Small Producer Program have closed.

Archive of Closed RFPs

Thu, 13 Jun 2013 19:55:05 GMT

Previous RFPs have been archived. Please click on links below to access. The RFPs are in PDF format. You must have the current version of Adobe Reader in order to open the documents. Small Producer Program, 2012The Small Producer Program RFP for 2012. (977 KB) Unconventional Gas and Other Petroleum Resources Program, 2012 The Unconventional Gas and Other Petroleum Resources Program RFP for 2012, (886 KB) Ultra-Deepwater Program, 2011 The Ultra-Deepwater Program RFP2011UDW001, (1.4 MB) The Ultra-Deepwater Program RFP2011UDW002, (1.3 MB) Unconventional Gas and Other Petroleum Resources Program, 2011 The Unconventional Gas and Other Petroleum Resources Program RFP for 2011, (906 KB) Small Producer Program 2011 The Small Producer Program RFP for 2011, (964 KB) Ultra-Deepwater Program, 2010 UDW Follow-on Phases (RFP2010UDW001), (732 KB) UDW Need 1 Technical Area of Interest (RFP2010UDW002), (1.2 MB) UDW Need 3 Technical Area of Interest (RFP2010UDW003), (839 KB) UDW...

Request for Proposals

Thu, 13 Jun 2013 19:49:27 GMT

RESEARCH PARTNERSHIP TO SECURE ENERGY FOR AMERICA (Update 06/13/13) RPSEA anticipates releasing the 2012 Requests for Proposals (RFPs) for the Ultra-Deepwater program during the third quarter of 2013. (RFPs are in PDF format. In order to fully utilize these forms you must have the current version of Adobe Reader. If you don't have Adobe Reader or you need the current version, you can download it here.) RPSEA Solicitation Process General Questions, (Updated 10/08/09), PDF, (87 KB) Small Producer Program The Small Producer Program RFP2012SP001 closed on 06/12/13 at 4:00 PM. Unconventional Resources Program The Uncoventional Resources Program RFP2012UN001 closed on 06/05/13 at 4:00 PM. Ultra-Deepwater Program The Ultra-Deepwater Program 2012 RFPs are expected to be released during the third quarter of 2013. Back to top Quick Links Archive of Closed RFP's

Standard Contract Documents

Tue, 11 Jun 2013 19:13:46 GMT

Listed below are standard contract documents that will need to be completed by subcontractors. (Some documents are in PDF format. If you do not have Adobe Reader, you can download it here.) Sample Subcontract Documents:These documents are not required to be submitted with a proposal. However, you are encouraged to review the Sample Subcontract Document applicable to your organization prior to submitting a technical proposal. Sample Subcontract for Commercial or Non-Profit Firms Word Sample Subcontract for Educational Institutions Word Sample Subcontract for National Laboratories Word Cost/Price Proposal Documents: The Cost/Price Volume is not submitted with a technical proposal but will be required after selection before award. Instructions for Preparation of Cost-Price Volume PDF Cost Reimbursement Contract Cost Estimate Word Cost Share Form Word Subcontractor Acquired Property Checklist Word Subcontracted Effort Form ...

Unconventional Resources Past Events

Sat, 08 Jun 2013 22:57:02 GMT

Summary of Results from Completed GTI Marcellus Shale R&D Project May 7, 2013Hilton Garden Inn Pittsburgh/Southpointe, Canonsburg, PA Agenda Released Presentations Meeting Overview - Kent Perry, Vice President, Onshore Programs, RPSEA 356 KB) Marcellus Shale R&D Project Description – Iraj Salehi, Gas Technology Institute (486 KB) Project Overview and Operator Perspective on Collaborative R&D Projects – Joe Frantz, Range Resources (2.5 MB) Natural Fracture Attributes in the Marcellus: Spatial Organization – Dr. Julia Gale, University of Texas - Austin, Bureau of Economic Geology (3.1 MB) Nanometer-scale Imaging and Evaluation of Marcellus Shale – Dr. Timothy Kneafsey, Lawrence Berkeley National Laboratory (11.3 MB) Analysis and Flow Properties of Marcellus Shale and Gas – Dr. Roland Horne, Stanford University (2.2 MB) Full Field Reservoir Modeling of a Marcellus Shale Asset, using Hard Data – Dr. Shahab Mohaghegh, West Virginia University (2.5 MB)...

Diagnosis of Multiple Fracture Stimulation in Horizontal Wells by Downhole Temperature Measurement for Unconventional Oil and Gas Wells (10122-43)

Sat, 08 Jun 2013 20:57:22 GMT

Texas A&M University - Principal Investigator: Dr. Ding Zhu

Objective: The objectives of the project is to develop novel approaches to using temperature data to diagnose stimulation treatments, to estimate fracture geometry, and to evaluate fractured well performance in unconventional tight sand and shale reservoirs.

Period of Performance: November 7, 2011 to September 30, 2014

Abstract

Project Fact Sheet

Development of Plasma Technology for Water Management of Frac/Produced Water (11122-31)

Sat, 08 Jun 2013 06:46:02 GMT

Drexel University - Principal Investigator: Young I Cho

Objective: The objective is to develop an integrated plasma water treatment system for improved water management for frac/produced water.

Period of Performance: April 09, 2013 to April 09, 2015

Project Fact Sheet

Hybrid Rotor Compression for Multiphase and Liquids-Rich Wellhead Production Applications (11123-15)

Sat, 08 Jun 2013 06:30:02 GMT

OsComp Systems Inc. - Principal Investigator: Jeremy Pitts Objective: The objective of this work is to develop OsComp’s hybrid rotor compression technology into a robust and commercially viable solution which can be used as a multiphase compression solution for wet gas applications in small producer environments. This is an R&D project intended to iterate upon the existing technology and optimize it for wet gas applications in a small package. The project’s objective is to prove that OsComp’s technology can work with wet gas streams at high efficiencies in a manner which will prove beneficial to small producers. The project begins with OsComp’s pre-existing technology being further tested and analyzed to inform the redesign of the system. The updated design will be built into a second generation prototype which will be tested in OsComp’s facilities under controlled conditions. Once OsComp’s engineering team has tested the compressor under...

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noemail@rpsea.org — Thu, 08 Mar 2007 19:20:50 GMT

Objectives:

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Release Date: 8-Mar-07 1:20 PM
Expiration Date: 8-Jun-07 1:20 PM

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2007-03-08T19:20:50Z

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