The agreements that govern the indebtedness incurred or assumed in connection with the acquisition contain various covenants that impose restrictions on us and certain of our subsidiaries that may affect our ability to operate our businesses.
The agreements that govern the indebtedness incurred or assumed in connection with the CareFusion transaction contain various affirmative and negative covenants that may, subject to certain significant exceptions, restrict our ability and the ability of certain of our subsidiaries (including CareFusion) to, among other things, have liens on their property, transact business with affiliates and/or merge or consolidate with any other person or sell or convey certain of our assets to any one person.
In addition, some of the agreements that govern our indebtedness contain financial covenants that will require us to maintain certain financial ratios.
Our ability and the ability of our subsidiaries to comply with these provisions may be affected by events beyond our control.
Failure to comply with these covenants could result in an event of default, which, if not cured or waived, could accelerate our repayment obligations.
Item 1B.
Unresolved Staff Comments.
None.
Item 2.
Properties.
BD’s executive offices are located in Franklin Lakes, New Jersey.
As of October 31, 2016, BD owned or leased 255 facilities throughout the world, comprising approximately 19,796,011 square feet of manufacturing, warehousing, administrative and research facilities.
The U. S.  facilities, including those in Puerto Rico, comprise approximately 7,459,856 square feet of owned and 2,923,257 square feet of leased space.
The international facilities comprise approximately 7,189,652 square feet of owned and 2,223,245 square feet of leased space.
Sales offices and distribution centers included in the total square footage are also located throughout the world.
Operations in each of BD’s business segments are conducted at both U. S.  and international locations.
Particularly in the international marketplace, facilities often serve more than one business segment and are used for multiple purposes, such as administrative/sales, manufacturing and/or warehousing/distribution.
BD generally seeks to own its manufacturing facilities, although some are leased.
The following table summarizes property information by business segment.
## Table 0 ##
(A) Facilities used by more than one business segment.
BD believes that its facilities are of good construction and in good physical condition, are suitable and adequate for the operations conducted at those facilities, and are, with minor exceptions, fully utilized and operating at normal capacity.
The U. S.  facilities are located in Alabama, Arizona, California, Connecticut, Florida, Georgia, Illinois, Indiana, Maryland, Massachusetts, Michigan, Nebraska, New Jersey, North Carolina, Ohio, Oklahoma, South Carolina, Texas, Utah, Virginia, Washington, D. C. , Washington, Wisconsin and Puerto Rico.
The international facilities are as follows: - Europe, Middle East, Africa, which includes facilities in Austria, Belgium, Bosnia and Herzegovina, the Czech Republic, Denmark, England, Finland, France, Germany, Ghana, Hungary, Ireland, Italy, Kenya, Luxembourg, Netherlands, Norway, Poland, Portugal, Russia, Saudi Arabia, South Africa, Spain, Sweden, Switzerland, Turkey, the United Arab Emirates and Zambia.
Noble Energy, Inc.
Supplemental Oil and Gas Information (Unaudited) 117 Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities (Unaudited) (1) Costs incurred in connection with crude oil and natural gas acquisition, exploration and development are as follows:
## Table 1 ##
(1) Costs incurred include capitalized and expensed items.
(2) Other International includes the North Sea, Ecuador (through November 24, 2010), China, Argentina (through February 2008), Nicaragua and other new ventures.
See Note 3.
Acquisitions and Divestitures.
(3) Proved property acquisition costs include $352 million related to the Central DJ Basin asset acquisition in 2010, a $6 million downward purchase price adjustment related to the Mid-Continent acquisition in 2009, and $254 million related to the MidContinent acquisition in 2008.
(4) Unproved property acquisition costs include $146 million related to the Central DJ Basin asset acquisition, $38 million for deepwater Gulf of Mexico lease blocks and the remainder for other onshore US lease acquisitions primarily in Wattenberg in 2010; $56 million for deepwater Gulf of Mexico lease blocks and the remainder primarily for other onshore US lease acquisitions in 2009; and $179 million for deepwater Gulf of Mexico lease blocks, $38 million related to the Mid-Continent acquisition, $39 million related to lease acquisitions in East Texas, and the remainder primarily for other onshore US lease acquisitions in 2008.
(5) 2010 exploration costs include drilling and completion costs of $62 million in deepwater Gulf of Mexico and $41 million in Israel.2009 exploration costs include drilling and completion costs of $57 million in deepwater Gulf of Mexico, $19 million in Equatorial Guinea and $71 million in Israel.2008 exploration costs include drilling and completion costs of $72 million in deepwater Gulf of Mexico, $98 million in Equatorial Guinea and $25 million in Israel.
(6) Worldwide development costs include amounts spent to develop PUDs of approximately $1.1 billion in 2010, $440 million in 2009, and $528 million in 2008.
Equatorial Guinea development costs include non-cash accruals related to estimated construction progress to date on an FSPO to be used in the development of the Aseng field of $266 million in 2010 and $29 million in 2009.
These capitalized costs are included in development costs as the FPSO is constructed.
US development costs include increases in asset retirement obligations of $15 million in 2010, $11 million in 2009, and $34 million in 2008.
Other international development costs include increases in asset retirement obligations of $2 million in 2010, $5 million in 2009, and $18 million in 2008.
included the payment of cash dividends on our common stock ($115 million), the repayment of installment and other notes ($32 million) and the repurchase of stock ($3 million).
Acquisition, Capital and Other Exploration Expenditures Acquisition, Capital and Other Exploration Expenditures Information for investing activities (on an accrual basis) is as follows:
## Table 2 ##
(1) Unproved property acquisition cost for 2010 includes $146 million related to the Central DJ Basin asset acquisition, $38 million for deepwater Gulf of Mexico lease blocks, and the remainder for other US onshore lease acquisitions primarily in Wattenberg.
Unproved property acquisition cost for 2009 includes $56 million for deepwater Gulf of Mexico lease blocks and the remainder primarily for other onshore US lease acquisition.
Unproved property acquisition cost for 2008 includes $179 million for deepwater Gulf of Mexico lease blocks, $38 million related to the Mid-Continent acquisition, $39 million related to lease acquisitions in East Texas, and the remainder primarily for other onshore US lease acquisitions.
(2) Proved property acquisition cost for 2010 includes $352 million related to Central DJ Basin asset acquisition.
Proved property acquisition cost for 2008 includes $254 million related to the Mid-Continent acquisition.
(3) Relates to estimated construction progress to date on an FSPO to be used in the development of the Aseng field, offshore Equatorial Guinea.
Total expenditures in 2010 doubled as compared with 2009 due to major development project expenditures and the Central DJ Basin asset acquisition.
In addition, seismic and dry hole expense increased.
Total expenditures in 2009 decreased by $947 million, or 42%, as compared with 2008, as we reduced our capital spending program in response to economic conditions.
Asset Sales In August 2010, we sold certain non-core assets in the Mid-Continent and Illinois Basin areas for cash proceeds of $552 million.
In 2008, we sold our Argentina assets for a sales price of $117.5 million.
Risk and Insurance Program Our business is subject to all of the operating risks normally associated with the exploration, production, gathering, processing and transportation of crude oil and natural gas, including hurricanes, blowouts, well cratering and fire, any of which could result in damage to, or destruction of, oil and natural gas wells or formations or production facilities and other property and injury to persons.
As protection against financial loss resulting from many, but not all of these operating hazards, we maintain insurance coverage, including certain physical damage, business interruption (loss of production), employer’s liability, comprehensive general liability and worker’s compensation insurance.
We maintain insurance at levels that we believe are appropriate and consistent with industry practice and we regularly review our potential risks of loss and the cost and availability of insurance and revise our insurance program accordingly.
For example, in certain international locations (including Israel and Equatorial Guinea) we carry business interruption insurance for loss of revenue arising from physical damage to our facilities caused by fire and natural disasters.
The coverage is subject to customary deductibles, waiting periods and recovery limits.
In the Gulf of Mexico, we have begun self-insuring for windstorm exposure.
We made this decision because recent abandonment activities on the Gulf of Mexico shelf significantly reduced our windstorm exposure, as our remaining Gulf of Mexico assets are primarily subsea operations.
In addition, the cost of windstorm insurance has recently increased while the amounts of coverage have been reduced.
Therefore, we believe it is more cost-effective for us to self-insure these assets.
However, we are now responsible for substantially all windstorm-related damages to our Gulf of Mexico assets.
In accordance with industry practice, oil and gas well owners generally indemnify drilling rig contractors against certain risks, such as those arising from property and environmental losses, pollution from sources such as oil spills, or contamination resulting from well blowout or fire or other uncontrolled flow of hydrocarbons.
Most of our domestic and international drilling contracts contain such indemnification clauses.
In addition, oil and gas well owners typically assume all costs of well control in the event of an uncontrolled well.
We currently carry insurance protection for our net share of any potential financial losses occurring as a result of events such as the Deepwater Horizon Incident.
This protection consists of $250 million of well control, pollution cleanup and consequential damages coverage and $251 million of additional pollution cleanup and consequential damages coverage, which also covers third party personal injury and death.
Consequently if we were to experience an accident similar to the Deepwater Horizon
Table of Contents Noble Energy, Inc.  Index to Financial Statements Notes to Consolidated Financial Statements 115 Undeveloped Leasehold Costs Undeveloped leasehold costs as of December 31, 2016 totaled $2.2 billion, including $2.1 billion related to onshore US unproved properties, $105 million related to deepwater Gulf of Mexico unproved properties, and $32 million related to international unproved properties.
We evaluate our exploration opportunities as part of our periodic impairment review.
If, based upon a change in exploration plans, availability of capital and suitable rig and drilling equipment, resource potential, comparative economics, changing regulations and/or other factors, an impairment is indicated, we record either (1) impairment expense related to individually significant leases or (2) a decrease in the valuation of our pool of individually insignificant leases.
During 2016, we completed our geological evaluation of certain deepwater Gulf of Mexico and offshore Falkland Islands leases and licenses and determined that several, representing $127 million of undeveloped leasehold cost, should be relinquished or exited.
As a result, we recognized $93 million of undeveloped leasehold impairment expense and recorded a $34 million decrease in our valuation pool of individually insignificant leases.
Note 7.
Equity Method Investments Equity Method Investments Equity method investments are included in other noncurrent assets in the consolidated balance sheets, and our share of earnings is reported as income from equity method investees in the consolidated statements of operations.
Our share of income taxes incurred directly by the equity method investees is reported in income from equity method investees and is not included in our income tax provision in our consolidated statements of operations.
Investments accounted for under the equity method consist primarily of the following: ?50% interest in CONE Gathering LLC (CONE Gathering), which owns and operates natural gas gathering facilities servicing our properties in the Marcellus Shale; ?33.5% interest in CONE Midstream Partners, LP (CONE Midstream), a public master limited partnership, which constructs, owns and operates natural gas gathering and other midstream energy assets in support of our Marcellus Shale activities; ?45% interest in Atlantic Methanol Production Company, LLC (AMPCO), which owns and operates a methanol plant and related facilities in Equatorial Guinea; and ?28% interest in Alba Plant LLC (Alba Plant), which owns and operates a liquefied petroleum gas processing plant in Equatorial Guinea.
CONE Midstream Dropdown Transaction In fourth quarter 2016, CONE Midstream, completed its first acquisition of midstream assets (dropdown) from CONE Gathering since its initial public offering in 2014.
CONE Gathering subsequently distributed $70 million cash and additional CONE Midstream common units to us.
We currently own 7,110,638 common units and 14,581,560 subordinated units of CONE Midstream.
Equity method investments are as follows:

Tables referenced above, in order (Table 0 first):
<table><tr><td>Sites</td><td>Corporate</td><td>BD Life Sciences</td><td>BD Medical</td><td>Mixed(A)</td><td>Total</td></tr><tr><td>Leased</td><td>11</td><td>19</td><td>75</td><td>92</td><td>195</td></tr><tr><td>Owned</td><td>3</td><td>15</td><td>31</td><td>121</td><td>60</td></tr><tr><td>Total</td><td>14</td><td>34</td><td>106</td><td>103</td><td>255</td></tr><tr><td>Square feet</td><td>1,425,720</td><td>4,337,963</td><td>9,891,908</td><td>4,140,420</td><td>19,796,011</td></tr></table>
<table><tr><td></td><td>United States</td><td>Equatorial Guinea</td><td>Israel</td><td>Other Int'l-2</td><td>Total</td></tr><tr><td>(millions)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Year Ended December 31, 2010</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Property Acquisition Costs</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Proved-3</td><td>$352</td><td>$-</td><td>$-</td><td>$-</td><td>$352</td></tr><tr><td>Unproved-4</td><td>304</td><td>1</td><td>-</td><td>-</td><td>305</td></tr><tr><td>Total Acquisition Costs</td><td>656</td><td>1</td><td>-</td><td>-</td><td>657</td></tr><tr><td>Exploration Costs-5</td><td>306</td><td>6</td><td>52</td><td>54</td><td>418</td></tr><tr><td>Development Costs-6</td><td>964</td><td>596</td><td>236</td><td>75</td><td>1,871</td></tr><tr><td>Total Consolidated Operations</td><td>$1,926</td><td>$603</td><td>$288</td><td>$129</td><td>$2,946</td></tr><tr><td>Year Ended December 31, 2009</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Property Acquisition Costs</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Proved-3</td><td>$-5</td><td>$-</td><td>$-</td><td>$-</td><td>$-5</td></tr><tr><td>Unproved-4</td><td>89</td><td>1</td><td>-</td><td>2</td><td>92</td></tr><tr><td>Total Acquisition Costs</td><td>84</td><td>1</td><td>-</td><td>2</td><td>87</td></tr><tr><td>Exploration Costs-5</td><td>189</td><td>30</td><td>81</td><td>13</td><td>313</td></tr><tr><td>Development Costs-6</td><td>711</td><td>100</td><td>33</td><td>129</td><td>973</td></tr><tr><td>Total Consolidated Operations</td><td>$984</td><td>$131</td><td>$114</td><td>$144</td><td>$1,373</td></tr><tr><td>Year Ended December 31, 2008</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Property Acquisition Costs</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Proved-3</td><td>$256</td><td>$-</td><td>$-</td><td>$-</td><td>$256</td></tr><tr><td>Unproved-4</td><td>296</td><td>-</td><td>-</td><td>6</td><td>302</td></tr><tr><td>Total Acquisition Costs</td><td>552</td><td>-</td><td>-</td><td>6</td><td>558</td></tr><tr><td>Exploration Costs-5</td><td>322</td><td>105</td><td>28</td><td>62</td><td>517</td></tr><tr><td>Development Costs-6</td><td>1,106</td><td>38</td><td>13</td><td>108</td><td>1,265</td></tr><tr><td>Total Consolidated Operations</td><td>$1,980</td><td>$143</td><td>$41</td><td>$176</td><td>$2,340</td></tr></table>
<table><tr><td></td><td colspan="3">Year Ended December 31,</td></tr><tr><td></td><td>2010</td><td>2009</td><td>2008</td></tr><tr><td>(millions)</td><td></td><td></td><td></td></tr><tr><td>Acquisition, Capital and Exploration Expenditures</td><td></td><td></td><td></td></tr><tr><td>Unproved Property Acquisition-1</td><td>$305</td><td>$92</td><td>$302</td></tr><tr><td>Proved Property Acquisition-2</td><td>352</td><td>-</td><td>256</td></tr><tr><td>Exploration</td><td>343</td><td>242</td><td>448</td></tr><tr><td>Development</td><td>1,520</td><td>881</td><td>1,193</td></tr><tr><td>Corporate and Other</td><td>121</td><td>102</td><td>65</td></tr><tr><td>Total</td><td>$2,641</td><td>$1,317</td><td>$2,264</td></tr><tr><td>Increase in FPSO Lease Obligation-3</td><td>$266</td><td>$29</td><td>$-</td></tr></table>

Question: If the Total Acquisition Costs in terms of United States develops with the same growth rate in 2010, what will it reach in 2011? (in million)
Answer: 5123.05
Reasoning program: subtract(656,84), divide(#0,84), add(1,#1), multiply(656,#2)