EXECUTIVE OVERVIEW

Organization
We are a leading provider of services and products to the energy industry. We serve the upstream oil and natural gas industry throughout the lifecycle of the reservoir, from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production through the life of the field. Activity levels within our operations are significantly impacted by spending on upstream exploration, development, and production programs by major, national, and independent oil and natural gas companies. We report our results under two segments, Completion and Production and Drilling and Evaluation:
- our Completion and Production segment delivers cementing, stimulation, intervention, pressure control, specialty chemicals, artificial lift, and completion services. The segment consists of Halliburton Production Enhancement, Cementing, Completion Tools, Boots & Coots, and Multi-Chem; and
- our Drilling and Evaluation segment provides field and reservoir modeling, drilling, evaluation, and precise wellbore placement solutions that enable customers to model, measure, and optimize their well construction activities. The segment consists of Halliburton Drill Bits and Services, Wireline and Perforating, Testing and Subsea, Baroid, Sperry Drilling, Landmark Software and Services, and Consulting and Project Management.

The business operations of our segments are organized around four primary geographic regions: North America, Latin America, Europe/Africa/CIS, and Middle East/Asia. We have significant manufacturing operations in various locations, including, but not limited to, the United States, Canada, the United Kingdom, Malaysia, Mexico, Brazil, and Singapore. With over 70,000 employees, we operate in approximately 80 countries around the world, and our corporate headquarters are in Houston, Texas and Dubai, United Arab Emirates. Financial results
During the first half of 2012, we produced revenue of $14.1 billion and operating income of $2.2 billion, reflecting an operating margin of approximately 16%. Revenue increased $2.9 billion, or 26%, from the first half of 2011, while operating income increased $249 million, or 13%. These results were attributable to higher drilling activity in the oil and liquids-rich basins in North America, as well as increased activity in all our international regions, compared to the first half of 2011. The first half of 2012 results, however, were moderated by escalating costs associated with guar gum, a blending additive used in our hydraulic fracturing processes, decreasing activity in natural gas basins, and pricing pressure in certain basins in North America due to an over-supply of hydraulic fracturing equipment. The first half of 2012 results included a $300 million, pre-tax, loss contingency for the Macondo well incident. The first half of 2011 results were negatively impacted by an $11 million, pre-tax, charge for employee separation costs in the Eastern Hemisphere and a $59 million, pre-tax, charge in Libya, primarily related to reserves for certain assets.
Business outlook
We continue to believe in the strength of the long-term fundamentals of our business. Energy demand is expected to increase in the long term driven by economic growth in developing countries despite current underlying downside risks in the industry, such as sluggish growth in developed countries and supply uncertainties associated with geopolitical tensions in the Middle East. Furthermore, development of new resources is expected to be more complex resulting in increasing service intensity.
In North America, the industry is experiencing a shift from natural gas shale plays to oil and liquids-rich shale plays due to low natural gas prices resulting from continued strong natural gas production despite peak natural gas storage levels. We believe we will continue to see a modest reduction in natural gas drilling over the remainder of the year as operators optimize their budgets by focusing on basins with better economics. While oil and liquids-rich drilling has mostly offset the decline in the first half of 2012, we believe the recent volatility in oil prices and softness in natural gas liquids prices may prompt certain customers to adopt a more cautious tone for the remainder of 2012. We anticipate near-term pricing pressure for our production enhancement services in certain markets and continued cost inflation related to guar gum.
Our Gulf of Mexico business continues to recover due to an increase in the level of permit approvals for deepwater drilling. We remain optimistic about the recovery of activity in the Gulf of Mexico as our customers adapt to new regulations and new permit approvals are issued. In addition, more deepwater rigs are expected to arrive in the Gulf of Mexico over the course of this year. We believe that an increasing pace of permit applications and approvals needs to be sustained in order for the Gulf of Mexico business to recover to activity levels experienced before the Macondo well incident. See "Business Environment and Results of Operations."

Outside of North America, revenue and operating income increased in the first half of 2012 compared to the first half of 2011.We believe competitive pricing for large, long-term international projects will continue throughout 2012. However, for the remainder of the year, we expect to see gradual activity improvements as new rigs, particularly in deepwater, enter the international markets. We also believe that new international unconventional oil and natural gas projects may contribute to activity improvements this year. Recently, our operations in Egypt have recovered from the turmoil experienced in the first quarter of 2011. Although some minor work has been performed in Libya, we are still awaiting well-defined operational plans from our customers. We do not expect activity levels in Libya to recover to pre-2011 levels until late 2012 or 2013.
We are continuing to execute several key initiatives in 2012. These initiatives include increasing manufacturing production in the Eastern Hemisphere and reinventing our service delivery platform to lower our delivery costs. Our operating performance and business outlook are described in more detail in "Business Environment and Results of Operations." Financial markets, liquidity, and capital resources The global financial markets continue to be somewhat volatile. While this has created additional risks for our business, we believe we have invested our cash balances conservatively and secured sufficient financing to help mitigate any near-term negative impact on our operations. For additional information, see "Liquidity and Capital Resources" and "Business Environment and Results of Operations."

LIQUIDITY AND CAPITAL RESOURCES

We ended the second quarter of 2012 and the year ended December 31, 2011 with cash and equivalents of $2.2 billion and $2.7 billion. As of June 30, 2012, approximately $416 million of the $2.2 billion of cash and equivalents was held by our foreign subsidiaries that would be subject to tax if repatriated. If these funds are needed for our operations in the United States, we would be required to accrue and pay United States taxes to repatriate these funds. However, our intent is to permanently reinvest these funds outside of the United States and our current plans do not demonstrate a need to repatriate them to fund our United States operations. We also held $50 million of short-term, United States Treasury securities at June 30, 2012 compared to $150 million at December 31, 2011 included in "Other current assets" on our condensed consolidated balance sheets.
Significant sources of cash
Cash flows from operating activities contributed $1.1 billion to cash in the first half of 2012.
During the first half of 2012, we sold or redeemed approximately $200 million of short-term marketable securities.
Significant uses of cash
Capital expenditures were $1.7 billion in the first half of 2012, and were predominantly made in Halliburton Production Enhancement, Sperry Drilling, Cementing, and Wireline and Perforating. We have also invested additional working capital to support the growth of our business.
During the first six months of 2012, inventories increased by $727 million, primarily because we procured a large reserve of guar gum when market prices were relatively high. See further discussion in "North America operations." We paid $167 million in dividends to our shareholders in the first half of 2012. During the first half of 2012, we purchased $100 million in short-term marketable securities.
Future uses of cash. Capital spending for 2012 is expected to range between $3.6 billion to $3.8 billion. The capital expenditures plan for 2012 is primarily directed toward Halliburton Production Enhancement, Sperry Drilling, Cementing, and Wireline and Perforating.
We are continuing to explore opportunities for acquisitions that will enhance or augment our current portfolio of services and products, including those with unique technologies or distribution networks in areas where we do not already have large operations.
Subject to Board of Directors approval, we expect to pay dividends of approximately $80 million per quarter during 2012. We also have approximately $1.7 billion remaining available under our share repurchase authorization, which may be used for open market share purchases. Other factors affecting liquidity
Guarantee agreements. In the normal course of business, we have agreements with financial institutions under which an aggregate of approximately $1.8 billion of letters of credit, bank guarantees, or surety bonds were outstanding as of June 30, 2012, including $284 million of surety bonds related to Venezuela. See "Business Environment and Results of Operations - International Operations" for further discussion related to Venezuela. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization.
Financial position in current market. We have $2.2 billion of cash and equivalents and $50 million in investments in marketable securities as of June 30, 2012 and a total of $2.0 billion of available committed bank credit under our revolving credit facility. Furthermore, we have no financial covenants or material adverse change provisions in our bank agreements and our debt maturities extend over a long period of time. Although a portion of earnings from our foreign subsidiaries is reinvested outside the United States indefinitely, we do not consider this to have a significant impact on our liquidity. We currently believe that our capital expenditures, working capital investments, and dividends, if any, in 2012 can be fully funded through cash from operations.
As a result, we believe we have a reasonable amount of liquidity and, if necessary, additional financing flexibility given the current market environment to fund our potential contingent liabilities, if any. However, as discussed above in Note 6 to the condensed consolidated financial statements, there are numerous future developments that may arise as a result of the Macondo well incident that could have a material adverse effect on our liquidity. Credit ratings. Credit ratings for our long-term debt remain A2 with Moody's Investors Service and A with Standard & Poor's. The credit ratings on our short-term debt remain P-1 with Moody's Investors Service and A-1 with Standard & Poor's.
Customer receivables. In line with industry practice, we bill our customers for our services in arrears and are, therefore, subject to our customers delaying or failing to pay our invoices. In weak economic environments, we may experience increased delays and failures to pay our invoices due to, among other reasons, a reduction in our customers' cash flow from operations and their access to the credit markets. For example, we continue to see delays in receiving payment on our receivables from one of our primary customers in Venezuela. If our customers delay in paying or fail to pay us a significant amount of our outstanding receivables, it could have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial condition.

BUSINESS ENVIRONMENT AND RESULTS OF OPERATIONS

We operate in approximately 80 countries to provide a comprehensive range of discrete and integrated services and products to the energy industry. The majority of our consolidated revenue is derived from the sale of services and products to major, national, and independent oil and natural gas companies worldwide. We serve the upstream oil and natural gas industry throughout the lifecycle of the reservoir, from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production throughout the life of the field. Our two business segments are the Completion and Production segment and the Drilling and Evaluation segment. The industries we serve are highly competitive with many substantial competitors in each segment. In the first half of 2012, based upon the location of the services provided and products sold, 56% of our consolidated revenue was from the United States. In the first half of 2011, 54% of our consolidated revenue was from the United States. No other country accounted for more than 10% of our revenue during these periods.
Operations in some countries may be adversely affected by unsettled political conditions, acts of terrorism, civil unrest, force majeure, war or other armed conflict, expropriation or other governmental actions, inflation, foreign currency exchange restrictions, and highly inflationary currencies. We believe the geographic diversification of our business activities reduces the risk that loss of operations in any one country, other than the United States, would be materially adverse to our consolidated results of operations.
Activity levels within our business segments are significantly impacted by spending on upstream exploration, development, and production programs by major, national, and independent oil and natural gas companies. Also impacting our activity is the status of the global economy, which impacts oil and natural gas consumption.
Some of the more significant measures of current and future spending levels of oil and natural gas companies are oil and natural gas prices, the world economy, the availability of credit, government regulation, and global stability, which together drive worldwide drilling activity. Our financial performance is significantly affected by oil and natural gas prices and worldwide rig activity, which are summarized in the following tables.
This table shows the average oil and natural gas prices for West Texas Intermediate (WTI), United Kingdom Brent crude oil, and Henry Hub natural gas:

                                                       Three Months Ended             Year Ended
                                                             June 30                  December 31
Average Oil Prices (dollars per barrel)               2012              2011             2011
West Texas Intermediate                         $      93.73        $    102.61     $       95.13
United Kingdom Brent                                  108.92             117.78            111.53

Average United States Natural Gas
Prices (dollars per thousand cubic feet, or
Mcf)
Henry Hub                                       $       2.26        $      4.38     $        4.09

The quarterly and year-to-date average rig counts based on the Baker Hughes Incorporated rig count information were as follows:

                                            Three Months Ended               Six Months Ended
                                                  June 30                         June 30
Land vs. Offshore                           2012           2011             2012             2011
United States:
Land                                         1,924          1,798          1,936              1,744
Offshore (incl. Gulf of Mexico)                 46             32             44                 29
Total                                        1,970          1,830          1,980              1,773
Canada:
Land                                           171            187            381                386
Offshore                                         2              1              2                  1
Total                                          173            188            383                387
International (excluding Canada):
Land                                           923            847            901                854
Offshore                                       306            299            308                302
Total                                        1,229          1,146          1,209              1,156
Worldwide total                              3,372          3,164          3,572              3,316
Land total                                   3,018          2,832          3,218              2,984
Offshore total                                 354            332            354                332

                                            Three Months Ended               Six Months Ended
                                                  June 30                         June 30
Oil vs. Natural Gas                         2012           2011             2012             2011
United States (incl. Gulf of Mexico):
Oil                                          1,372            946          1,317                879
Natural gas                                    598            884            663                894
Total                                        1,970          1,830          1,980              1,773
Canada:
Oil                                            118            114            271                258
Natural gas                                     55             74            112                129
Total                                          173            188            383                387
International (excluding Canada):
Oil                                            980            894            961                902
Natural gas                                    249            252            248                254
Total                                        1,229          1,146          1,209              1,156
Worldwide total                              3,372          3,164          3,572              3,316
Oil total                                    2,470          1,954          2,549              2,039
Natural gas total                              902          1,210          1,023              1,277


                                            Three Months Ended               Six Months Ended
                                                  June 30                         June 30
Drilling Type                               2012           2011             2012             2011
United States (incl. Gulf of Mexico):
Horizontal                                   1,169          1,039          1,170              1,009
Vertical                                       569            561            585                538
Directional                                    232            230            225                226
Total                                        1,970          1,830          1,980              1,773

Our customers' cash flows, in most instances, depend upon the revenue they generate from the sale of oil and natural gas. Lower oil and natural gas prices usually translate into lower exploration and production budgets. The opposite is true for higher oil and natural gas prices.
WTI oil spot prices fluctuated throughout 2011 between a low of approximately $75 per barrel to a high of approximately $113 per barrel. Brent oil spot prices fluctuated between a low of approximately $94 per barrel to a high of approximately $127 per barrel during this same period. During the first half of 2012, WTI and Brent oil spot prices averaged approximately $98 and $113 per barrel, respectively, consistent with prices experienced in the first half of 2011. Significant decreases, however, have occurred in the second quarter of 2012 as geopolitical tension in the Middle East, global economic uncertainty surrounding the European debt crisis, and the threat of a slowdown in the Chinese economy have impacted demand. The outlook for world petroleum demand for the remainder of 2012 remains mixed, with the International Energy Agency's July 2012 "Oil Market Report" continuing to forecast 2012 demand to increase approximately 1% over 2011 levels.
Natural gas prices in the United States have declined approximately 45% from the first half of 2011 due to the resiliency of natural gas production coupled with natural gas inventories above five-year historical levels. In response, our customers have curtailed natural gas drilling activity. Despite recent improvement in spot prices, we believe that downward pressure on natural gas prices will continue through the summer injection season. The United States Energy Information Administration's July 2012 "Short Term Energy Outlook" forecast a continued shift in electricity generation from coal to natural gas, but we foresee significant price constraints in the near-term as natural gas competes as a fuel source in the power generation market.
In spite of this tempered outlook, we believe that, over the long term, hydrocarbon demand will generally increase. Increased demand, combined with the underlying trends of smaller and more complex reservoirs, high depletion rates, and the need for continual reserve replacement, should drive the long-term need for our services and products.
North America operations
Depressed natural gas prices can impact our customers' drilling and production activities, particularly in North America. The decline in natural gas prices compared to the first half of 2011 has accelerated the shift from natural gas shale plays to oil and liquids-rich shale plays. For the first half of 2012, the average natural gas directed rig count fell by 248 rigs, or 24%, from the first half of 2011, while the average oil directed rig count has increased by 460 rigs, or 41%, over the same period. This transition has resulted in additional relocation costs and inefficiencies, which negatively impacted our margins in the first half of 2012. Increased costs for certain raw materials, particularly for guar gum, also adversely affected our margins in the second quarter of 2012. The seasonal Canadian spring break-up, a period when road conditions hinder the movement of heavy equipment, had a negative impact on our results in the second quarter of 2012 due to the growth we have experienced in this market in recent years. We anticipate that this market will recover in the second half of the year as road conditions improve. In the long run, we believe the shift to oil and liquids-rich shale basins will continue to drive increased service intensity, but also in fluid chemistry and other technologies required for these complex reservoirs. Production enhancement pricing, however, may be challenging as competition increases in these oil and liquids-rich plays and our contracts come up for renewal.
In May 2010, the United States Department of the Interior effectively suspended all offshore deepwater drilling projects in the United States Gulf of Mexico. The suspension was lifted in October 2010, but permits were not issued for an extended period of time, and we experienced a significant reduction in our Gulf of Mexico operations. In the first quarter of 2011, the issuance of drilling permits resumed. Deepwater drilling activity in the Gulf of Mexico continues to recover due to an increase in drilling permit approvals. We believe we will see an increase in the level of permit approvals through the remainder of 2012, leading to additional deepwater rigs arriving in the Gulf of Mexico. Over the long term, our results in the Gulf of Mexico are dependent on, among other things, governmental approvals for permits, our customers' actions, and the potential movement of deepwater rigs to or from other markets. International operations
In 2011, pricing pressures from over capacity and geopolitical disruptions in North Africa had a negative impact on international operating income. In the second half of 2012 and into 2013, we continue to anticipate that the industry will experience steady volume increases as macroeconomic trends support a more favorable operator spending outlook and new rigs are scheduled to enter the market. We believe these trends will eventually lead to meaningful absorption of equipment supply. The average international rig count has improved by 53 rigs, or 5%, since the first half of 2011. Despite this increased volume, we continue to believe that international pricing will remain competitive, particularly for larger projects. We also believe that international unconventional oil and natural gas and deepwater projects will contribute to activity improvements, and we plan to leverage our extensive experience in North America to optimize these opportunities. Consistent with our long-term strategy to grow our operations outside of North America, we also expect to continue to invest capital in our international operations.
Venezuela. As of June 30, 2012, our total net investment in Venezuela was approximately $247 million. In addition to this amount, we have $284 million of surety bond guarantees outstanding relating to our Venezuelan operations.

Initiatives
Following is a brief discussion of some of our recent and current initiatives:
- increasing our market share in the more economic, unconventional plays, mature fields, and deepwater markets by leveraging our broad technology offerings to provide value to our customers through integrated solutions and the ability to more efficiently drill and complete their wells;
- exploring opportunities for acquisitions that will enhance or augment our current portfolio of services and products, including those with unique technologies or distribution networks in areas where we do not already have large operations;
- making key investments in technology and capital to accelerate growth opportunities. To that end, we are continuing to push our technology and manufacturing development, as well as our supply chain, closer to our customers in the Eastern Hemisphere;
- improving working capital, and managing our balance sheet to maximize our financial flexibility. We are deploying a global project to improve service delivery that we expect to result in, among other things, additional investments in our systems and significant improvements to our current order-to-cash and purchase-to-pay processes;
- continuing to seek ways to be one of the most cost efficient service providers in the industry by using our scale and breadth of operations; and
- expanding our business with national oil companies.

RESULTS OF OPERATIONS IN 2012 COMPARED TO 2011

Three Months Ended June 30, 2012 Compared with Three Months Ended June 30, 2011

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