Electric Supply The electricity O&R sold to its full-service customers in 2015 was purchased under firm power contracts or through the wholesale electricity market.
The company expects that these resources will again be adequate to meet the requirements of its customers in 2016.
O&R does not own any electric generating capacity.
The company plans to meet its continuing obligation to supply electricity to its customers through a combination of electricity purchased under contracts or purchased through the wholesale electricity market.
To reduce the volatility of its customers’ electric energy costs, the company has contracts to purchase electric energy and enters into derivative transactions to hedge the costs of a portion of its expected purchases.
For information about the company’s contracts, see Note O to the financial statements in Item 8.
In general, the Utilities recover their purchased power costs, including the cost of hedging purchase prices, pursuant to rate provisions approved by the state public utility regulatory authority having jurisdiction.
See “Financial and Commodity Market Risks – Commodity Price Risk,” in Item 7 and “Recoverable Energy Costs” in Note A to the financial statements in Item 8.
From time to time, certain parties have petitioned the NYSPSC to review these provisions, the elimination of which could have a material adverse effect on the Companies’ financial position, results of operations or liquidity.
Gas Operations Gas Facilities O&R’s capitalized costs for utility plant, net of accumulated depreciation for gas facilities, which are primarily distribution facilities, were $502 million and $476 million at December 31, 2015 and 2014, respectively.
O&R and Pike own their gas distribution systems and O&R owns a gas transmission system.
Natural gas is delivered by pipeline to O&R at various points in or near its service territory and is distributed to customers by the company through an estimated 1,876 miles of mains and 105,482 service lines.
Gas Sales and Deliveries O&R generally recovers the cost of the gas that it buys and then sells to its full-service customers.
It does not make any margin or profit on the gas it sells.
O&R’s gas revenues are subject to a weather normalization clause.
O&R’s New York gas revenues (which accounted for substantially all of O&R’s gas revenues in 2015) are subject to a revenue decoupling mechanism.
As a result, its gas delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.
O&R’s gas sales and deliveries for the last five years were:
## Table 0 ##
LUBRICANTS AND SPECIALTY PRODUCTS OPERATIONS Our lubricants and specialty products operations consist of our Petro-Canada Lubricants and Tulsa rack forward businesses.
Our Petro-Canada Lubricants business produces automotive, industrial and food grade lubricants and greases, base and process oils and specialty fluids and is the largest manufacturer of high margin Group III base oils in North America and is the world's largest producer of pharmaceutical white oils.
Products are marketed in 80 countries worldwide to a diverse customer base through a global sales force and distributor network.
Our Tulsa Refinery produces high quality base oils, process oils, waxes, horticultural oils and asphalt performance products.
Products are marketed worldwide through strategically located terminals in the United States and selected distributors internationally.
The following table sets forth information about our lubricants and specialty products operations and includes our Petro-Canada Lubricants business for the period February 1, 2017 (date of acquisition) through December 31, 2017.
## Table 1 ##
PCLI owns and operates a refinery located in Mississauga, Ontario having lubricant production capacity of 15,600 barrels per stream day and has the flexibility to match unique lubricant product formulations.
The primary operating units include a hydrogen plant and hydrotreating, solvent dewaxing, hydrodentrification, catalytic dewaxing and hydrobon/platformer units.
The Mississauga plant also includes packaging facilities and has extensive distribution capabilities with marine, truck and rail access.
HOLLY ENERGY PARTNERS, L. P.  HEPis a Delaware limited partnership that trades on the New York Stock Exchange under the trading symbol “HEP.
” HEPowns and operates logistic assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and refinery processing units that principally support our refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain regions of the United States and Delek's refinery in Big Spring, Texas.
Additionally, HEP owns a 75% interest in UNEV Pipeline, LLC (“UNEV”), the owner of a pipeline running from Woods Cross, Utah to Las Vegas, Nevada (the “UNEV Pipeline”) and associated product terminals; a 50% interest in Osage Pipe Line Company, LLC, the owner of a pipeline running from Cushing, Oklahoma to El Dorado, Kansas (the “Osage Pipeline”); and a 50% interest in Cheyenne Pipeline, LLC, the owner of a pipeline running from Fort Laramie, Wyoming to Cheyenne, Wyoming (the “Cheyenne Pipeline”).
HEP generates revenues by charging tariffs for transporting petroleum products and crude oil through its pipelines, by leasing certain pipeline capacity to Delek, by charging fees for terminalling and storing refined products and other hydrocarbons and providing other services at its storage tanks, terminals and refinery processing units.
HEP does not take ownership of products that it transports, terminals, stores or refines; therefore, it is not directly exposed to changes in commodity prices.
HEP's recent acquisitions (2015 through present) are summarized below: SLC Pipeline and Frontier Aspen On October 31, 2017, HEPacquired the remaining 75% interest in SLC Pipeline LLC, the owner of a pipeline that serves refineries in the Salt Lake City, Utah area (the “SLC Pipeline”), and the remaining 50% interest in Frontier Aspen LLC, the owner of a pipeline running from Wyoming to Frontier Station, Utah (the “Frontier Pipeline”), from subsidiaries of Plains All American Pipeline, L. P.  (“Plains”) for total cash consideration of $250.0 million.
Item 7.
Management’s Discussion and Analysis of Financial Condition and Results of Operations We are a global integrated energy company with significant operations in the North America, Africa and Europe.
Our operations are organized into four reportable segments: ?
Exploration and Production (“E&P”) which explores for, produces and markets liquid hydrocarbons and natural gas on a worldwide basis.  ?
Oil Sands Mining (“OSM”) which mines, extracts and transports bitumen from oil sands deposits in Alberta, Canada, and upgrades the bitumen to produce and market synthetic crude oil and vacuum gas oil.  ?
Integrated Gas (“IG”) which markets and transports products manufactured from natural gas, such as liquefied natural gas (“LNG”) and methanol, on a worldwide basis.  ?
Refining, Marketing & Transportation (“RM&T”) which refines, markets and transports crude oil and petroleum products, primarily in the Midwest, upper Great Plains, Gulf Coast and southeastern regions of the United States.
Certain sections of Management’s Discussion and Analysis of Financial Condition and Results of Operations include forward-looking statements concerning trends or events potentially affecting our business.
These statements typically contain words such as “anticipates,” “believes,” “estimates,” “expects,” “targets,” “plans,” “projects,” “could,” “may,” “should,” “would” or similar words indicating that future outcomes are uncertain.
In accordance with “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, these statements are accompanied by cautionary language identifying important factors, though not necessarily all such factors, which could cause future outcomes to differ materially from those set forth in the forward-looking statements.
We hold a 60 percent interest in Equatorial Guinea LNG Holdings Limited (“EGHoldings”).
As discussed in Note 4 to the consolidated financial statements, effective May 1, 2007, we ceased consolidating EGHoldings.
Our investment is accounted for using the equity method of accounting.
Unless specifically noted, amounts presented for the Integrated Gas segment for periods prior to May 1, 2007, include amounts related to the minority interests.
Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the information under Item 1.  Business, Item 1A.
Risk Factors, Item 6.
Selected Financial Data and Item 8.
Financial Statements and Supplementary Data.
Overview Exploration and Production Prevailing prices for the various grades of crude oil and natural gas that we produce significantly impact our revenues and cash flows.
Prices were volatile in 2009, but not as much as in the previous year.
Prices in 2009 were also lower than in recent years as illustrated by the annual averages for key benchmark prices below.
## Table 2 ##
llar, ongoing concerns about supplies of crude oil, and geopolitical risk.
Later in 2008, crude oil prices sharply declined as the U. S.  dollar rebounded and global demand decreased as a result of economic recession.
The price decrease continued into 2009, but reversed after dropping below $33.98 in February, ending the year at $79.36.
Our domestic crude oil production is about 62 percent sour, which means that it contains more sulfur than light sweet WTI does.
Sour crude oil also tends to be heavier than light sweet crude oil and sells at a discount to light sweet crude oil because of higher refining costs and lower refined product values.
Our international crude oil production is relatively sweet and is generally sold in relation to the Dated Brent crude benchmark.
The differential between WTI and Dated Brent average prices narrowed to $0.42 in 2009 compared to $2.49 in 2008 and $0.02 in 2007.

Tables referenced above, in order (Table 0 first):
<table><tr><td></td><td colspan="5">Year Ended December 31,</td></tr><tr><td></td><td>2011</td><td>2012</td><td>2013</td><td>2014</td><td>2015</td></tr><tr><td>Gas Delivered(MDt)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Firm Sales</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Full service</td><td>8,384</td><td>7,539</td><td>8,808</td><td>9,529</td><td>9,348</td></tr><tr><td>Firm transportation</td><td>10,823</td><td>10,505</td><td>12,062</td><td>12,592</td><td>11,752</td></tr><tr><td>Total Firm Sales</td><td>19,207</td><td>18,044</td><td>20,870</td><td>22,121</td><td>21,100</td></tr><tr><td>Interruptible Sales</td><td>4,184</td><td>4,326</td><td>4,118</td><td>4,216</td><td>4,205</td></tr><tr><td>Total Gas Delivered to O&R Customers</td><td>23,391</td><td>22,370</td><td>24,988</td><td>26,337</td><td>25,305</td></tr><tr><td>Transportation of customer-owned gas</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Sales for resale</td><td>864</td><td>793</td><td>885</td><td>945</td><td>906</td></tr><tr><td>Sales to electric generating stations</td><td>24</td><td>15</td><td>19</td><td>70</td><td>25</td></tr><tr><td>Off-System Sales</td><td>—</td><td>—</td><td>—</td><td>3</td><td>62</td></tr><tr><td>Total Sales</td><td>24,279</td><td>23,178</td><td>25,892</td><td>27,355</td><td>26,298</td></tr></table>
<table><tr><td></td><td colspan="3">Years Ended December 31,</td></tr><tr><td>Lubricants and Specialty Products</td><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Throughput (BPD)</td><td>21,710</td><td>—</td><td>—</td></tr><tr><td>Sales of produced refined products (BPD)</td><td>31,480</td><td>12,030</td><td>11,140</td></tr><tr><td>Sales of produced refined products:</td><td></td><td></td><td></td></tr><tr><td>Finished products</td><td>45%</td><td>50%</td><td>52%</td></tr><tr><td>Base oils</td><td>31%</td><td>50%</td><td>48%</td></tr><tr><td>Other</td><td>24%</td><td>—%</td><td>—%</td></tr><tr><td>Total</td><td>100%</td><td>100%</td><td>100%</td></tr></table>
<table><tr><td>Benchmark</td><td>2009</td><td>2008</td><td>2007</td></tr><tr><td>WTI crude oil (Dollars per barrel)</td><td>$62.09</td><td>$99.75</td><td>$72.41</td></tr><tr><td>Dated Brent crude oil (Dollars per barrel)</td><td>$61.67</td><td>$97.26</td><td>$72.39</td></tr><tr><td>Henry Hub natural gas (Dollars per mcf)<sup>(a)</sup></td><td>$3.99</td><td>$9.04</td><td>$6.86</td></tr></table>

Question: by what percentage did the average henry hub natural gas benchmark decrease from 2007 to 2009?
Answer: -0.41837
Reasoning program: subtract(3.99,6.86), divide(#0,6.86)