Friday, December 15, 2017

Cuba takes over Venezuela stake in refinery joint venture

http://translatingcuba.com/wp-content/uploads/2016/10/refineria-venezolano-Camilo-Cienfuegos-EFE_CYMIMA20161031_0013_13.jpg

https://www.reuters.com/article/cuba-venezuela/cuba-takes-over-venezuela-stake-in-refinery-joint-venture-idUSL8N1OE79H

HAVANA/HOUSTON, Dec 14 (Reuters) - Venezuela has pulled out of a partnership with Cuba in its Cienfuegos oil refinery and the Caribbean island has taken full ownership of the plant, Cuban state media said on Thursday. 

Venezuela is grappling with a crippling economic crisis that already forced it to slash cheap oil shipments to Cuba, which has had a knock-on effect on the island’s ailing economy. 

The reason for the dissolution of the partnership was not immediately obvious. A former Venezuelan government official said Cuba had taken Venezuelan state oil-firm PDVSA’s 49 percent stake in the Cienfuegos refinery as payment for debts it said the country incurred.
The source added that Cuba said Venezuela owed it for professional services provided as well as the rental of tankers. 

PDVSA’s Cuba unit was unable to provide immediate comment. Cuba’s state-run oil monopoly Cubapetroleo (Cupet), which runs the refinery, did not respond to a request for comment. 

“Since August 2017, the Cienfuegos refinery has been operating as a fully Cuban state entity,” the ruling Communist Party’s newspaper Granma wrote. 

The Cienfuegos refinery is a Soviet-era facility configured to run Russian crude that was later upgraded by PDVSA to convert up to 65,000 barrels per day (bpd) of Venezuelan oil into refined products for Cuba’s domestic market and exports. 

It processed just 8 million barrels of crude in 2017 (roughly 24,000 barrels per day), Granma reported, indicating it was operating well below capacity due to lower shipments of oil from Venezuela. 

A lack of medium and light oil had forced PDVSA this year to change the quality of the crude shipped to the island to heavier grades, which are more difficult to process at Cienfuegos. 

Cuba has long relied on the OPEC nation for about 70 percent of its fuel needs. But shipments have fallen by as much as 40 percent since 2014 and Cuba is looking for new suppliers to help mitigate electricity and fuel rationing to state companies. 

Cuba took a delivery of oil from Russia in May, helping compensate somewhat for that drop, and Russian oil major Rosneft said in October it was looking to expand cooperation. 

That could mean increased deliveries to Cuba, joint extraction projects as well as cooperation to modernize the Cienfuegos refinery, Rosneft said. 

Venezuela remains Cuba’s top ally and President Nicolas Maduro was due to stop off in Havana on Thursday as he returned from a conference in Turkey, newspaper El Nacional reported. 

Still, lower Venezuela oil supplies and a cash crunch have forced Cuba to slash imports and reduce the use of fuel and electricity over the past two years. 

This helped tip its centrally planned economy into recession in 2016 for the first time in nearly a quarter century. The government is expected to give an estimate for economic performance this year at the twice-annual parliamentary session next week. (Reporting by Sarah Marsh in Havana and Marianna Parraga in Houston; Editing by Andrew Hay)

Wednesday, December 13, 2017

The Noose Tightens: Venezuela Struggles To Ship Oil

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https://oilprice.com/Energy/Crude-Oil/The-Noose-Tightens-Venezuela-Struggles-To-Ship-Oil.html

The picture for Venezuela grows grimmer by the day, as tankers waiting to load fuel oil from Venezuela ports grow in number as the national oil company, PDVSA, struggles to deliver the amounts needed to load. That’s what traders and shipping data from Reuters have revealed in recent days.

According to this data, there are four tankers waiting to load crude oil and fuel oil at the port of Paraguana and another eight waiting at the Jose port—PDVSA’s largest export terminal—to load refined oil products. There are also ten vessels waiting to unload refined products for the Venezuelan market, but payments to the sellers have been delayed, and now so is unloading.

Venezuela has been struggling to rein in the decline of its crude oil production resulting from underinvestment, mismanagement, and, most recently, U.S. sanctions. In October, crude oil production fell to the lowest in nearly 30 years, as PDVSA is unable to pay for services rendered by oilfield service providers, who are now refusing to continue working with it.

To add insult to injury, the country’s largest refinery, Paraguana, suffered damages from a fire earlier this month, which caused a severe drop in capacity utilization to just 13 percent. The refinery has a daily capacity of 955,000 barrels of crude. Related: Are NatGas Prices About To Explode?

Venezuela’s fuel oil production also declined as a result of the outages following the fire and a drop in the input of medium and light crude in the distillation units where the oil product is made.

Over the last four years, crude oil production in Venezuela has fallen by about a million bpd, and in October the daily average was below 2 million bpd. Exports are also falling: in October, PDVSA exported 475,165 bpd to the United States, which was down 12 percent on September and 36 percent on October 2016. That’s the lowest daily export rate for the last 14 years.

By Irina Slav for Oilprice.com

Tuesday, December 12, 2017

Unfazed by OPEC, Libya and Nigeria seek to boost oil output

https://fm.cnbc.com/applications/cnbc.com/resources/img/editorial/2017/05/12/104466181-OPEC_flag_sign.jpg?v=1494593072

https://www.reuters.com/article/us-opec-oil-output/unfazed-by-opec-libya-and-nigeria-seek-to-boost-oil-output-idUSKBN1E61CJ

Less than two weeks after OPEC’s decision to extend oil production cuts, Libya and Nigeria – the only two exempt members of the group – are signaling their intent to raise output next year.
FILE PHOTO: A man fixes a sign with OPEC's logo next to its headquarter's entrance before a meeting of OPEC oil ministers in Vienna, Austria, November 29, 2017. REUTERS/Heinz-Peter Bader
 
While several ministers at the Nov. 30 meeting of the Organization of the Petroleum Exporting Countries suggested the two nations had joined the output-curbing deal, both are working to add to their peak production from this year. 

On Friday, oil company Total said its new Egina field offshore Nigeria was on track to start next year – adding 10 percent to the country’s production. 

The field will have a capacity of 200,000 barrels per day (bpd) and launch in the fourth quarter of 2018, counterbalancing production constrained by aging pipelines, perpetual theft and sabotage. 

“That could certainly change the dynamics,” said Ehsan Ul-Haq, head of crude and products at Resource Economist, a consultancy. 

The Nigerian petroleum ministry did not respond to a request for comment on the Egina field startup, and whether production elsewhere would be curtailed as a result. 

On Saturday, the head of Libya’s U.N.-backed government met the head of Libya’s National Oil Corp (NOC) and the governor of Tripoli’s central bank to discuss how the corporation could get more cash to raise oil output next year. 

The NOC received a quarter of its requested budget in 2017, hampering efforts to sustain oil output near 1 million bpd. 

Any additional funds could help make crucial repairs to the country’s energy infrastructure, a regular target for militant attacks, and boost output above the roughly 1 million bpd mark where it currently stands. 

Libya’s NOC has so far not spoken officially about the OPEC deal and declined a Reuters request for comment.

NO CAPS

The developments may come as a surprise to market observers, who, after the Nov. 30 meeting, believed Nigeria and Libya had agreed to participate in the OPEC agreement by imposing official caps at their peak 2017 production levels. 

Instead, the two countries merely provided their production outlook for 2018 and an assessment that the combined total would not exceed 2.8 million bpd, their forecast output for 2017, two sources familiar with the matter told Reuters. 

That outlook was dependent on both countries’ finances and security situation, one of those sources said. 

The headline of a statement issued by Nigeria’s petroleum ministry on the day of the OPEC meeting stressed, in block capitals, that Nigeria and Libya were exempt from cuts. 

Oil Minister Emmanuel Ibe Kachikwu emphasized in the statement that the nation’s condensates - a form of ultra-light crude - were exempt from any total, giving it leeway in calculations. He also told local media there was “no obligation” to do anything. 

Oil production from the two countries has averaged 1.7 million bpd and 900,000 bpd, respectively, this year according to Reuters assessments. 

But it has swung in each country in a range of 340,000-350,000 bpd.
Editing by Dale Hudson

Monday, December 11, 2017

China’s Sinopec Looking to Sell Nigeria Business

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China’s Sinopec Group has hired BNP Paribas to sell its oil business in Nigeria and Gabon, three people with knowledge of the matter said, as the state-owned oil giant pares back its presence in Africa.

Sinopec and other oil groups including China National Petroleum Corp and CNOOC made large acquisitions between 2009 and 2013 with the help of low-cost loans from Chinese state-owned banks.
The hunt for overseas assets was intended to bulk up their energy reserves and meet future demand from China, the world’s second-largest economy.

But oil prices fell to about $27 a barrel in 2016 from more than $100 in 2014, making some of these investments unprofitable.

Benchmark Brent Crude oil is now trading at more than $60. Militants have also recently attacked oil and gas facilities in Nigeria, further discouraging Sinopec.

China’s economy, which was growing strongly when the company expanded, has also slowed. “Sinopec is trying to sever ties,” one of the people told Reuters.”It has hired BNP to sell (its) assets in Nigeria and Gabon.

A Sinopec spokesman did not respond to requests for comment and a BNP Paribas spokeswoman declined to comment.

Sinopec spent $7.24bn in 2009 for Switzerland-based Addax Petroleum, its largest ever foreign oil acquisition, to secure land in Nigeria, Gabon, Cameroon and Iraq that was licensed for extraction and exploration.

It offered considerable potential as commodity prices rose but bankers expect the Nigeria and Gabon assets to sell for less than $1bn. The sources said Sinopec was planning to sell Addax’s onshore and offshore oil and gas production sites in Nigeria and Gabon.

Sinopec’s Cameroon operation would be its only remaining project in Africa.

We’ve already seen several Chinese companies divest some of their overseas assets,” said a second person, who asked not to be named.”At the current oil prices, such investments (are not) economically viable for Chinese companies.”

The sources said Sinopec had also decided to sell Addax after a recent bribery investigation by Geneva prosecutors into payments made in Nigeria.

Addax agreed to pay 31mn Swiss francs to settle the bribery charges, for which its executive officer and legal director had also been charged, and shut its offices in Geneva, Houston and Aberdeen.

At the time, Addax said its parent company was closing the offices in response to low oil prices and did not comment on the investigations at the time. The Sinopec spokeswoman did not respond for a request for a comment on whether this was a reason for the sale.

Nigeria, Africa’s largest economy, fell into recession for the first time in 25 years in the second quarter of 2016, after militant groups attacked oil and gas facilities in its Delta region. That cut the country’s oil production dramatically.

Lower crude exports, Nigeria’s mainstay, meant less money in government coffers, especially the US dollars Nigeria needs to import essential products and keep businesses running.

The latest group of militants to emerge in the Delta earlier this year also threatened that oil facilities belonging to major international oil companies would be destroyed.

Sinopec’s assets in Nigeria and Gabon could attract the interest of companies already operating in the region including Perenco, which bought Total’s assets in Gabon for $350mn earlier this year, and Kosmos Energy, the sources said.

One of the people who spoke to Reuters said that Sinopec was looking to sell some of the Chinese company’s other exploration and drilling businesses outside China because of falling oil prices and regional political instability.

Sinopec has also agreed to sell its oil business in Argentina for $500mn to $600mn to Mexican company Vista Oil & Gas, according to sources, in part because of social unrest there.

Friday, December 8, 2017

Venezuela re-visited

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Leading shipbroker Gibson has once again highlighted the plight of Venezuela, by saying that the focus had now shifted to its huge $150 bill foreign debt. 
 
Around three weeks ago, Venezuela missed a deadline to make $200 mill interest payments on two government bonds, resulting in Standard & Poor’s formally declaring the first default.
 
About the same time, the Venezuelan president stated the country’s intention to restructure its foreign debt and the Russian Finance Ministry announced that the two countries had signed a debt restructuring deal, allowing Caracas to make “minimal” payments to Moscow over the next six years to help it meet its obligations to other creditors.
 
Politics and geopolitics aside, the economic challenges faced by Venezuela have direct implications on the domestic oil sector. The country’s crude production has been in steady decline over the past couple of years, largely due to the lack of investment, the shortage of available funds and ill-maintained production infrastructure.
 
According to IEA data, crude output averaged just over 1.9 mill barrels per day in October, 2017, down by 0.55 mill barrels per day, or 22%, compared to October, 2015.
 
The decline in production has had negative implications for the country’s crude exports, although not to the same extent. Venezuela’s financial problems also hit its refining sector, where lack of maintenance has led to a notable decline in domestic throughput volumes, reducing the downward pressure on crude exports.  
 
Venezuelan crude trade to the US was one of the biggest consequences of the country’s economic and political problems. Between January and August of this year, crude shipments to the US averaged 0.69 mill barrels per day, down 175,000 barrles per day compared to the same period in 2015.
 
In addition, the EIA weekly estimates suggest that this trade has declined further in recent months, averaging just 0.5 mill barrels per day since early September. Interestingly, Venezuelan crude exports to China have increased. During the first eight months of this year, shipments to China averaged 0.44 mill barrels per day, up by 100,000 barrels per day, compared to the same period in 2015, Gibson said. .
 
Apart from direct trade implications, it was also reported by Reuters that PDVSA is increasingly delivering poor quality crude to its international customers, which has resulted in complaints, cancelled orders and demands for discounts. There are also reports of logistical issues and disputes over payments. For tonnage calling at Venezuelan ports, this translates into additional, and at times extended, delays and sporadic cancellations.
 
Despite their recent firming, oil prices are still below the level needed by Venezuela to balance its financial requirements. As such, the difficulties faced by the country at present are unlikely to disappear anytime soon.
 
The recent debt restructuring with Russia will help to ease the most immediate pressures but it is unlikely to be sufficient to reverse the slide in domestic crude production and exports, Gibson concluded.

Thursday, December 7, 2017

Goldman raises 2018 oil price forecast on robust OPEC commitment

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https://www.cnbc.com/2017/12/05/goldman-raises-2018-oil-price-forecast-after-opec-deal.html
  • Goldman lifted its Brent price forecast for next year to $62 a barrel and its WTI projection to $57.50 a barrel
  • "Of course, risks remain and we see these as skewed to the upside into 2018 on the risk of an over tightening, either because of new disruptions, demand exceeding our optimistic forecast of OPEC letting the stock draw run hot," Goldman analysts said
A stronger than anticipated OPEC-led commitment to extend production cuts will support prices through 2018, according to analysts at Goldman Sachs.

In a research note published late Monday, Goldman lifted its Brent price forecast for next year to $62 a barrel and its WTI projection to $57.50 a barrel. The revisions were up from $58 a barrel and $55 a barrel respectively.

While the OPEC-led deal "leaves room for an earlier exit than currently scheduled, we now reflect this resolve in our supply forecast, with full compliance for longer and a more modest exit rate," Goldman analysts said in the research note.

Oil prices have lost ground in the days following OPEC's deal with global producers last week. The 14-member cartel, Russia and nine other crude producers announced plans to extend their output cuts until the end of 2018.

The move was heavily telegraphed ahead of the decision, but oil producers had earlier indicated they could exit the deal if they feel the market was overheating.

'Risks remain' beyond 2018

"Of course, risks remain and we see these as skewed to the upside into 2018 on the risk of an over tightening, either because of new disruptions, demand exceeding our optimistic forecast of OPEC letting the stock draw run hot," Goldman analysts said.

However, Goldman said the response of shale oil and other producers to higher prices would likely incentivize OPEC and Russia to "pare back" their now greater capacity, thus leaving risks to prices skewed towards the downside over the long term.

The price of oil collapsed from near $120 a barrel in June 2014 due to weak demand, a strong dollar and booming U.S. shale production. OPEC's reluctance to cut output was also seen as a key reason behind the fall. But, the oil cartel soon moved to curb production — along with other oil-producing nations — in late 2016.

Brent crude traded at around $62.36 on Tuesday morning, down 0.14 percent, while U.S. crude was trading at $57.29, down 0.31 percent.

Sam MeredithDigital Reporter, CNBC.com

Wednesday, December 6, 2017

Oil falls as U.S. fuel stock build signals easing demand

 https://fm.cnbc.com/applications/cnbc.com/resources/img/editorial/2014/12/19/102285229-RTRM69Y.530x298.jpg?v=1469816923

https://www.reuters.com/article/us-global-oil/oil-falls-as-u-s-fuel-stock-build-signals-easing-demand-idUSKBN1E005Q

Oil fell 2 percent on Wednesday after a sharp rise in U.S. inventories of refined fuel suggested demand may be flagging, while U.S. crude production hit another weekly record.
A worker prepares to label barrels of lubricant oil at the state oil company Pertamina's lubricant production facility in Cilacap, Central Java, Indonesia November 6, 2017 in this photo taken by Antara Foto. Picture taken November 6, 2017. Antara Foto/Rosa Panggabean/ via REUTERS 
 
Government data showed that U.S. crude stocks fell 5.6 million barrels, more than expected, though that was partially the result of the closure of the Keystone pipeline after a leak in South Dakota in mid-November, which cut flows to Cushing, Oklahoma. That line reopened Tuesday. 

However, gasoline stocks rose by 6.8 million barrels and distillate inventories were up 1.7 million barrels, both exceeding expectations in a Reuters poll. 

That hit prices of both crude and products in a market which is already heavily tilted bullish and thus potentially vulnerable to a selloff, analysts said. 

Gasoline stocks tend to build in December, but at 221 million barrels of inventory, stocks are slightly above the five-year average for this time of year. 

U.S. crude production rose to 9.7 million barrels per day, another weekly record, though short of all-time records reached in the 1970s. That increase may undermine efforts by global producers to cut supply. 

Supply cuts by the Organization of the Petroleum Exporting Countries, Russia and other producers that were extended at a meeting last week for the whole of 2018 have helped lift Brent prices by more than 40 percent since June. 

Prices have slipped from November’s peak, which represented two-year highs. 

“The sentiment-driven support to crude oil prices has somewhat dissipated as market participants look beyond last week’s OPEC meeting,” said Abhishek Kumar, senior energy analyst at Interfax Energy’s Global Gas Analytics in London. 

Brent crude futures LCOc1 were down $1.23, or 2 percent, at $61.63 a barrel by 11:21 a.m. EST (1621 GMT), after reaching a session high of $62.93, while U.S. crude futures CLc1 dropped $1.29, or 2.3 percent, to $56.33. 

Russian Oil Minister Alexander Novak said it was too early to talk about exiting the OPEC agreement, and that the process would be gradual. Analysts such as Goldman Sachs have said that the expected rise in demand in 2018 would mostly be offset by U.S. and Canadian supply growth. 

U.S. oil production C-OUT-T-EIA has climbed by 15 percent since mid-2016 to 9.7 million bpd, close to levels of top producers Russia and Saudi Arabia. 

“With U.S. production, we’re still in the throes of seeing that go ever higher. There’s only going to be more production coming which is very problematic for OPEC non-OPEC deal adherence,” said John Kilduff, partner at Again Capital in New York. 

Additional reporting by Scott DiSavino and Julia Simon in New York; Henning Gloystein and Keith Wallis in Singapore; Editing by David Evans and Marguerita Choy

Monday, December 4, 2017

Southern California oil refineries ordered to monitor, publicize neighborhood air quality

Southern California oil refineries ordered to monitor, publicize neighborhood air quality 
The air monitoring rules come as a series of fires, explosions, flaring incidents and other emergencies has sent smoke, dust and other pollutants into neighborhoods in recent years. Above, PBF Energy's Torrance Refining Co. (Luis Sinco / Los Angeles Times) 

http://beta.latimes.com/local/lanow/la-me-ln-refinery-pollution-20171201-story.html

Oil refineries must install air quality monitors at their fence lines and pay for pollution monitoring systems in surrounding communities by 2020 under rules adopted by Southern California regulators.

The measures approved Friday by the South Coast Air Quality Management District board will provide the public with real-time information on refinery emissions, but do not include requirements that facilities reduce pollution when high levels are found.

The rules come as a series of fires, explosions, flaring episodes and other incidents has sent smoke, dust and other pollutants into the air in recent years, stirring community anxiety about the dangers of living near California refineries.

The region's eight major oil refineries in Carson, El Segundo, Paramount, Torrance and Wilmington will be required to make the pollution readings they collect available on a website.

The monitors — likely to include optical remote sensing devices and other new technologies — will measure 15 refinery pollutants, including smog-forming gases and toxic compounds like benzene, toluene and hydrogen cyanide. Regulators said the devices will provide data on routine emissions and accidental releases and also could help find and address leaks that might be going undetected.

Air district officials said the rules were drafted concurrently with legislation Gov. Jerry Brown signed in October that requires air monitors to be deployed at refinery fence lines and in nearby communities by 2020.

The measures earned praise from community groups, environmentalists and local officials who have long sought more information on what people near the sprawling facilities were breathing.

"Refinery emissions affect our communities at all times, especially our children," said Maria Ramos, a member of Communities for a Better Environment who lives near a refinery in Wilmington. "But we are not aware of the levels of emissions that are being spewed into the air or what chemicals we're being exposed to."

Mayor Albert Robles of Carson, home to two refineries, welcomed the monitoring but criticized the rule because it "does not provide a mechanism to address the health risks once the monitoring data is gathered and known" and "makes no requirements for the refineries to take action to control these emissions."

The Western States Petroleum Assn. supports the monitoring rules, Southern California region director Patty Senecal said.

The community monitoring network, paid for by fees charged to refineries, could include traditional fixed stations as well as remote sensors distributed throughout neighborhoods, officials said. The air district will consider suggestions from the public as it decides where to deploy those monitors.

The rules will phase in over the next two years, along with an array of other refinery monitoring standards being rolled out by state and federal officials. Those include U.S. Environmental Protection Agency rules requiring fence-line monitoring for benzene and other mandates under recent legislation that extended the state's cap-and-trade program for greenhouse gases.

Bay Area pollution regulators adopted similar requirements for fence-line monitoring at oil refineries last year.

Friday, December 1, 2017

Magellan Midstream Launches Open Season for Proposed Crude Oil Pipeline from the Permian and Eagle Ford Basins to Corpus Christi and Houston

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TULSA, Okla., Dec. 1, 2017 /PRNewswire/ -- Magellan Midstream Partners, L.P. (NYSE: MMP) announced today that it intends to develop a new pipeline and has launched an open season to assess customer interest to transport various grades of crude oil and condensate from the Permian and Eagle Ford Basins to multiple destinations in the Corpus Christi and Houston, Texas markets, including Magellan's existing crude oil terminals in these markets. All potential customers must submit binding commitments by 5:00 p.m. Central Time on Feb. 1, 2018.

The proposed project would include construction of an approximately 375-mile, 24-inch diameter pipeline from Crane to a location near Three Rivers, Texas, providing shippers the option to ultimately deliver crude oil and condensate from the Three Rivers area to the Houston area via a new 200-mile pipeline or to the Corpus Christi area via a new 70-mile pipeline. The potential pipeline system is expected to have an initial capacity of at least 350,000 barrels per day (bpd) with the ability to expand up to 600,000 bpd for each destination, if warranted by industry demand.

Additional pipeline extensions are being considered for Midland and Orla, Texas in the Permian Basin and Gardendale and Helena, Texas in the Eagle Ford Basin. Magellan previously announced the construction of a 60-mile, 24-inch Delaware Basin pipeline to deliver crude oil and condensate from Wink to Crane.

Subject to receipt of all necessary permits and approvals, the proposed pipeline could be operational by the end of 2019.

For customer inquiries about the open season, please contact Brant Easterling at (918) 574-7665 or brant.easterling@magellanlp.com. More information about the open season is available at www.magellanlp.com.

About Magellan Midstream Partners, L.P. 

Magellan Midstream Partners, L.P. (NYSE: MMP) is a publicly traded partnership that primarily transports, stores and distributes refined petroleum products and crude oil. The partnership owns the longest refined petroleum products pipeline system in the country, with access to nearly 50% of the nation's refining capacity, and can store approximately 100 million barrels of petroleum products such as gasoline, diesel fuel and crude oil. More information is available at www.magellanlp.com.
Portions of this document constitute forward-looking statements as defined by federal law. Although management of Magellan Midstream Partners, L.P. believes such statements are based on reasonable assumptions, actual outcomes may be materially different. Among the key risk factors that may have a direct impact on the opportunity described in this news release are: (1) the ability to negotiate and sign definitive agreements with potential customers; (2) the ability to obtain all required rights-of-way, permits and other governmental approvals on a timely basis; (3) price fluctuations and overall demand for crude oil and condensate; (4) changes in the partnership's tariff rates or other terms imposed by state or federal regulatory agencies; (5) the occurrence of an operational hazard or unforeseen interruption; (6) disruption in the debt and equity markets that negatively impacts the partnership's ability to finance its capital spending and (7) willingness to incur or failure of customers or vendors to meet or continue contractual obligations related to this potential pipeline. Additional information about issues that could lead to material changes in performance is contained in the partnership's filings with the Securities and Exchange Commission, including the partnership's Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2016 and subsequent reports on Forms 8-K and 10-Q. You are urged to carefully review and consider the cautionary statements and other disclosures made in those filings, especially under the heading "Risk Factors." Forward-looking statements made by the partnership in this release are based only on information currently known, and the partnership undertakes no obligation to revise its forward-looking statements to reflect events or circumstances learned of or occurring after today's date.


Contact: 
Investors: 
Media:

Paula Farrell 
Bruce Heine

(918) 574-7650 
(918) 574-7010