In addition to the historical data contained herein, this document includes forward-looking statements regarding future market strength, customer spending and order levels, revenues and earnings of the Company, as well as expectations regarding equipment deliveries, margins, profitability, the ability to control and reduce raw material, overhead and operating costs, cash generated from operations, legal fees, costs associated with, or any liability for, a number of lawsuits filed against the Company in connection with the Deepwater Horizon matter, capital expenditures and the use of existing cash balances and future anticipated cash flows made in reliance upon the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. The Company's actual results may differ materially from those described in any forward-looking statements. Any such statements are based on current expectations of the Company's performance and are subject to a variety of factors, some of which are not under the control of the Company, which can affect the Company's results of operations, liquidity or financial condition. Such factors may include overall demand for, and pricing of, the Company's products; the size and timing of orders; the Company's ability to successfully execute large subsea and drilling projects it has been awarded; the possibility of cancellations of orders in backlog; the Company's ability to convert backlog into revenues on a timely and profitable basis; the impact of acquisitions the Company has made or may make; changes in the price of (and demand for) oil and gas in both domestic and international markets; raw material costs and availability; political and social issues affecting the countries in which the Company does business; fluctuations in currency markets worldwide; and variations in global economic activity. In particular, current and projected oil and gas prices historically have generally directly affected customers' spending levels and their related purchases of the Company's products and services. As a result, changes in oil and gas price expectations may impact the demand for the Company's products and services and the Company's financial results due to changes in cost structure, staffing and spending levels the Company makes in response thereto. See additional factors discussed in "Factors That May Affect Financial Condition and Future Results" contained herein.

Because the information herein is based solely on data currently available, it is subject to change as a result of, among other things, changes in conditions over which the Company has no control or influence, and should not therefore be viewed as assurance regarding the Company's future performance. Additionally, the Company is not obligated to make public disclosure of such changes unless required under applicable disclosure rules and regulations.

SECOND QUARTER 2012 COMPARED TO SECOND QUARTER 2011

Market Conditions

Information related to a measure of drilling activity and certain commodity spot
and futures prices during each quarter and the number of deepwater floaters and
semis under contract at the end of each period follows:

                                              Three Months Ended
                                                   June 30,                 Increase (Decrease)
                                              2012           2011          Amount             %
Drilling activity (average number of
working rigs during period)(1):
United States                                   1,970          1,829             141            7.7 %
Canada                                            173            188             (15 )         (8.0 )%
Rest of world                                   1,229          1,146              83            7.2 %
Global average rig count                        3,372          3,163             209            6.6 %
Commodity prices (average of daily U.S.
dollar prices per unit during
period)(2):
West Texas Intermediate Cushing, OK
crude spot price per barrel in U.S.
dollars                                    $    93.30      $  102.28     $     (8.98 )         (8.8 )%
Henry Hub natural gas spot price per
MMBtu in U.S. dollars                      $     2.30      $    4.36     $     (2.06 )        (47.2 )%
Twelve-month futures strip price (U.S.
dollar amount at period end)(2):
West Texas Intermediate Cushing, OK
crude oil contract (per barrel)            $    87.14      $   98.03     $    (10.89 )        (11.1 )%
Henry Hub Natural Gas contract (per
MMBtu)                                     $     3.29      $    4.65     $     (1.36 )        (29.2 )%
Number of deepwater floaters and semis
under contract in competitive major
markets at period-end(3):
U.S. Gulf of Mexico                                34             28               6           21.4 %
Northwestern Europe                                41             37               4           10.8 %
West Africa                                        31             30               1            3.3 %
Southeast Asia and Australia                       26             23               3           13.0 %

(1) Based on average monthly rig count data from Baker Hughes
(2) Source: Bloomberg
(3) Source: ODS-Petrodata Ltd.

The average number of worldwide operating rigs increased slightly in the second quarter of 2012 as compared to the second quarter of 2011. Almost two-thirds of the increase was a result of higher United States activity levels largely reflecting the impact of unconventional resource opportunities in the region.

Crude oil prices (West Texas Intermediate, Cushing, OK) decreased for much of the latter half of the second quarter of 2012 after reaching a high of $106 per barrel in late April before closing the period at approximately $85 per barrel. On average, crude oil prices were 8.8% lower during the second quarter of 2012 as compared to the second quarter of 2011. The twelve-month futures price for crude oil at June 30, 2012 was relatively flat compared to spot prices near the end of the quarter.

Natural gas (Henry Hub) prices trended slightly upward during the second quarter of 2012 from their lowest levels in the last decade, closing at $2.74 per MMBtu. On average, prices during the second quarter of 2012 were down 47.2% as compared to the same period in 2011, due largely to increased supplies available in North America as a result of new unconventional resource developments and higher activity levels. The twelve-month futures strip price for natural gas at June 30, 2012 remains depressed at $3.29 per MMBtu. In response to the current low natural gas prices, many oil and gas exploration and production companies have indicated they have curtailed development activities for "dry gas" wells. This activity has shifted to areas that produce gas with a mixture of liquid hydrocarbons ("wet gas" wells); thus, there has not been a significant drop off of overall U.S. activity levels to date. Should the twelve-month futures strip price stay at current levels for a long period of time, the portion of the North American rig count directed to gas drilling could decline further, which could further impact the Company's future orders flow. Additionally, should the price of various liquid hydrocarbons drop dramatically, rather than shifting activities from dry gas wells to wet gas wells, customers may elect to curtail overall activity levels which could also further negatively impact the Company's future orders flow in the U.S.

Critical Accounting Policies

Goodwill - The Company reviews the carrying value of goodwill in accordance with accounting rules on impairment of goodwill, which require that the Company estimate the fair value of each of its reporting units annually, or when impairment indicators exist, and compare such amounts to their respective carrying values to determine if an impairment of goodwill is required. The estimated fair value of each reporting unit is determined using discounted future expected cash flow models (level 3 unobservable inputs) consistent with the accounting guidance for fair value measurements. Certain estimates and judgments are required in the application of the discounted cash flow models, including, but not limited to, estimates of future cash flows and the selection of a discount rate. Generally, this review is conducted during the first quarter of each annual period. The results of the 2012 test indicated that there was no impairment of goodwill. Should the Company's estimate of the fair value of any of its reporting units decline significantly in future periods due to changes in customer demand, market activity levels, interest rates or other factors which would impact future earnings and cash flow or market valuation levels of the Company or any of its reporting units, an impairment of goodwill could be required.

Goodwill at June 30, 2012 was nearly $2.0 billion, a large portion of which was allocated to the Company's Process & Compression Systems (PCS) segment, which includes the majority of the NATCO operations acquired in 2009. The Company's determination of the fair value of its Custom Process Systems (CPS) business within the PCS segment included assumptions for continued long-term improvements to recent results. As a result of competitive pressures during the economic downturn that began prior to the acquisition of the NATCO operations in 2009, the backlog of the CPS business has carried unusually low margins which have negatively impacted recent profitability. Additionally, the Company experienced operating inefficiencies during 2011 which continued into 2012. While management is taking steps to improve the financial results of CPS, should it continue to underperform expectations assumed in the Company's discounted cash flow calculations, an impairment of goodwill for this reporting unit could be required. Goodwill associated with the CPS business was approximately $572.4 million at June 30, 2012.

Consolidated Results

Net income for the second quarter of 2012 totaled $174.6 million, or $0.70 per diluted share, compared to net income for the second quarter of 2011 of $148.0 million, or $0.59 per diluted share.

Total revenues for the Company increased $312.6 million, or 18.0%, during the three months ended June 30, 2012 as compared to the three months ended June 30, 2011 on the strength of higher sales in the Company's Drilling & Production Systems (DPS) and Valves & Measurement (V&M) business segments.

• DPS segment revenues increased 15.3% in the second quarter of 2012 as compared to the second quarter of 2011 largely as a result of the impact of newly acquired businesses, as well as increased aftermarket activity levels which resulted in higher revenues in the surface and drilling equipment product lines.

• Revenues in the V&M segment were up 30.9% in the second quarter of 2012 as compared to the same period last year as increased worldwide activity levels resulted in double-digit increases in each of the segment's major new equipment product lines.

As a percent of revenues, cost of sales (exclusive of depreciation and amortization) increased from 69.7% during the second quarter of 2011 to 70.6% for the second quarter of 2012. Lower margins in the PCS segment, particularly in the Custom Process Systems and Reciprocating Compression product lines, accounted for the majority of the increase in the ratio.

Selling and administrative expenses increased $35.7 million, or nearly 14.3%, during the three months ended June 30, 2012 as compared to the three months ended June 30, 2011.

• Selling and administrative expenses were 13.9% of revenues for the second quarter of 2012 as compared to 14.4% for the second quarter of 2011.

• Nearly 92% of the dollar increase was due to higher employee and facility-related costs mainly as a result of increased business volumes, the impact of newly acquired businesses and international and aftermarket expansion efforts.

Depreciation and amortization expense totaled $63.6 million for the second quarter of 2012 as compared to $47.6 million during the second quarter of 2011, an increase of $16.0 million, due mainly to higher depreciation expense as a result of recent increased levels of capital spending for new equipment, facilities and the Company's enhanced business information systems, as well as the impact of recently acquired businesses.

Other costs consisted of:

                                                                   Three Months Ended
                                                                        June 30,
  ($ in millions)                                                 2012             2011

International pension settlement costs                         $      6.1       $        -
Acquisition integration costs                                         3.3                -
BOP litigation costs                                                  0.8             14.0
Mark-to-market impact on currency derivatives not designated
as accounting hedges                                                 (1.5 )              -
Severance, restructuring and other costs                              1.2              6.1
                                                               $      9.9       $     20.1

The Company's effective tax rate for the second quarter of 2012 was 21.7% compared to 21.0% for the second quarter of 2011. The increase in the effective tax rate was due primarily to certain tax benefits recognized in the second quarter of 2011 from tax planning strategies put in place in prior periods and resolution of uncertainties regarding certain other tax benefits. This effect was partially offset by a mix shift between domestic and international earnings and the effect of resolution of certain tax contingencies in both periods.

Segment Results

DPS Segment -

                                             Three Months Ended
                                                  June 30,                 Increase (Decrease)
($ in millions)                              2012          2011              $                %

Revenues                                   $ 1,155.8     $ 1,002.7     $      153.1           15.3 %
Income before income taxes                 $   176.1     $   161.4     $       14.7            9.1 %
Income before income taxes as a percent
of revenues                                     15.2 %        16.1 %            N/A           (0.9 )%

Orders                                     $ 1,617.2     $ 1,442.7     $      174.5           12.1 %
Backlog (at period-end)                    $ 5,155.3     $ 3,628.3     $    1,527.0           42.1 %

Revenues

The increase in revenues was mainly due to the impact of newly acquired businesses which accounted for almost 90% of the total change from the second quarter of 2011. Absent this effect,

• sales of surface equipment increased 10% largely as a result of higher revenues from rental equipment deployed in unconventional resource regions of North America, and

• drilling equipment sales were up 10% largely related to increased demand for spares and rig upgrades.

These increases were partially offset by lower subsea project activity levels, primarily offshore West Africa.

Income before income taxes as a percent of revenues

The ratio of income before income taxes as a percent of revenues declined by 0.9 percentage points from the second quarter of 2011 to the second quarter of 2012, primarily as a result of:

• an increase of 0.7 percentage points in the ratio of depreciation and amortization as a percent of revenues, related mainly to higher capital spending in recent periods on rental equipment and aftermarket facilities and higher amortization of acquired intangibles, and

• a 0.5 percentage-point increase in the ratio of selling and administrative costs to revenues. Selling and administrative costs increased in total 21% from the same period last year. Approximately 39% of the total dollar increase in selling and administrative costs in the second quarter of 2012 as compared to the second quarter of 2011 was from the impact of newly acquired businesses with the remainder mainly attributable to higher costs related to increased activity levels and worldwide aftermarket expansions.

This was partially offset by a decrease in the ratio of cost of sales to revenues during the second quarter of 2012 as compared to the second quarter of 2011. Margins improved approximately 3.3 percentage points due to a shift to higher volumes of higher-margin drilling and surface equipment sales. Most of this improvement was offset by a decline in subsea project margins resulting in a net improvement of 0.3 percentage points in total segment margins.

Excluding the impact of newly acquired businesses, total segment orders increased 5% in the second quarter of 2012 as compared to the same period last year. This increase was primarily attributable to:

• a 69% increase in orders for subsea equipment reflecting a doubling of the number of subsea trees awarded in the second quarter of 2012 as compared to the same period in 2011, and

• a 29% increase in orders for surface equipment, mainly due to increased demand for rental equipment in unconventional resource regions of North America and higher international activity levels, primarily in Latin America and the Asia-Pacific region.

These increases were largely offset by a 32% decline in drilling equipment orders as a result of the lower level of major project awards in the second quarter of 2012 as compared to the second quarter of 2011.

Over 80% of the increased level of backlog at June 30, 2012 as compared to June 30, 2011 was due to higher backlog in the drilling equipment product line due mainly to strong demand in previous periods for new equipment and aftermarket parts and services.

V&M Segment -

                                             Three Months Ended
                                                  June 30,                    Increase
($ in millions)                              2012          2011            $              %

Revenues                                   $   558.3     $   426.5     $   131.8          30.9 %
Income before income taxes                 $   111.1     $    75.5     $    35.6          47.2 %
Income before income taxes as a percent
of revenues                                     19.9 %        17.7 %         N/A           2.2 %

Orders                                     $   549.8     $   526.5     $    23.3           4.4 %
Backlog (at period-end)                    $ 1,144.0     $ 1,016.2     $   127.8          12.6 %

Revenues

Engineered valve sales increased 35% as compared to the same period in 2011 as a result of higher worldwide pipeline construction project activity levels. Better market conditions in North America and increased shipments from higher beginning-of-period backlog resulted in a 36% increase in sales of distributed valves as compared to the same period in 2011. Combined, these two product lines accounted for over three-fourths of the increase in total V&M segment sales.

Income before income taxes as a percent of revenues

The increase in the ratio of income before income taxes as a percent of revenues was due primarily to:

• a 2.8 percentage-point decrease in the ratio of selling and administrative expenses to revenues as a result of revenues increasing at a greater rate than selling and administrative expenses during the second quarter of 2012 as compared to the second quarter of 2011, and

• a 0.5 percentage-point decrease in the ratio of depreciation and amortization to revenues mainly resulting from the impact of increasing revenues in relation to relatively flat depreciation and amortization during the second quarter of 2012 as compared to the second quarter of 2011.

These decreases were offset by an increase of 1.1 percentage points in the ratio of cost of sales to revenue resulting from a mix change in the second quarter of 2012 compared to the second quarter of 2011.

Orders

Orders increased in all product lines except distributed valves, with measurement equipment orders accounting for nearly 60% of the total segment increase in the second quarter of 2012 as compared to the second quarter of 2011. The primary drivers for the changes were:

• increased project activity, primarily in North America, which contributed to a 15% increase in orders for process valves, a 24% increase in demand for measurement equipment and a 4% increase in orders for aftermarket parts and services. This was partially offset by

• a 10% decrease in orders for distributed valves as a result of weaker orders from Canadian customers.

Backlog (at period-end)

Backlog levels for the V&M segment increased almost 13% from June 30, 2011 due to improved demand across all major product lines with nearly three-fourths of the increase attributable to stronger demand for engineered and process valves.

PCS Segment -

                                              Three Months Ended
                                                   June 30,                 Increase (Decrease)
($ in millions)                               2012           2011             $                %

Revenues                                   $     339.6     $   311.9     $     27.7             8.9 %
Income before income taxes                 $      26.9     $    34.0     $     (7.1 )         (20.9 )%
Income before income taxes as a percent
of revenues                                        7.9 %        10.9 %          N/A            (3.0 )%

Orders                                     $     407.0     $   418.1     $    (11.1 )          (2.7 )%
Backlog (at period-end)                    $   1,154.3     $   875.1     $    279.2            31.9 %

Revenues

A 34% increase in sales of centrifugal compression equipment, mainly resulting from higher international shipments of new engineered equipment and plant air units, and a 9% increase in process systems sales, largely due to higher demand for process applications in unconventional resource markets, more than offset a 51% decline in shipments of Superior compressors, primarily resulting from a large international shipment of high speed packaged units that occurred in the second quarter of 2011, which did not repeat in the same period in 2012.

Income before income taxes as a percent of revenues

The decrease in the ratio of income before income taxes as a percent of revenues was due primarily to a 4.2 percentage-point increase in the ratio of cost of sales to revenues during the second quarter of 2012, due mainly to lower margins in the custom process systems business as a result of project and manufacturing delays and inefficiencies as well as the impact on margins of lower volumes in the reciprocating compression product line. This increase in the cost of sales ratio was partially offset by a 1.2 percentage-point improvement in the ratio of selling and administrative costs to revenues as these costs remained relatively flat while revenues increased 8.9% from the second quarter of 2011 to the second quarter of 2012.

Orders

Nearly 80% of the decrease in total segment orders for the second quarter of 2012 as compared to the second quarter of 2011 was due to a 4% decline in demand for new process systems applications, primarily resulting from a large international order for a custom process application received in the second quarter of 2011 that did not repeat in the second quarter of 2012.

Backlog (at period-end)

The increase in backlog at June 30, 2012 as compared to June 30, 2011 was split fairly evenly between the compression equipment business and the process systems business. Over 68% of the increase in compression equipment backlog was due to recent high demand in the centrifugal engineered product line. Backlog in the process systems business was up nearly 30% largely as a result of a large order for new custom equipment received in a previous period.

Corporate Segment -

The $7.5 million increase in the loss before income taxes in the Corporate segment during the second quarter of 2012 as compared to the second quarter of 2011 (see Note 10 of the Notes to Consolidated Condensed Financial Statements) was due primarily to:

• a $9.9 million increase in selling and administrative expenses, due primarily to higher incentive compensation and other employee-related costs, including at certain international locations which report directly to the Corporate office,

• a $4.1 million increase in depreciation and amortization expense largely related to increased spending in recent periods for development of the Company's enhanced business information systems, and

• $4.1 million of foreign currency exchange losses incurred in the second quarter of 2012 on certain intercompany loans.

These increases were partially offset by a $10.2 million reduction in other costs as described above under "Consolidated Results".

SIX MONTHS ENDED JUNE 30, 2012 COMPARED TO SIX MONTHS ENDED JUNE 30, 2011

Market Conditions

Information related to a measure of drilling activity and certain commodity spot
and futures prices follows:

                                               Six Months Ended
                                                   June 30,                Increase (Decrease)
                                              2012          2011          Amount             %
Drilling activity (average number of
working rigs during period)(1):
United States                                   1,981         1,773             208           11.7 %
Canada                                            382           387              (5 )         (1.3 )%
Rest of world                                   1,209         1,156              53            4.6 %
Global average rig count                        3,572         3,316             256            7.7 %
Commodity prices (average of daily U.S.
dollar prices per unit during
period)(2):
West Texas Intermediate Cushing, OK
crude spot price per barrel in U.S.
dollars                                    $    98.11     $   98.40     $     (0.29 )         (0.3 )%
Henry Hub natural gas spot price per
MMBtu in U.S. dollars                      $     2.36     $    4.27     $     (1.91 )        (44.7 )%
Twelve-month futures strip price (U.S.
dollar amount at period end)(2):
West Texas Intermediate Cushing, OK
crude oil contract (per barrel)            $    87.14     $   98.03     $    (10.89 )        (11.1 )%
Henry Hub Natural Gas contract (per
MMBtu)                                     $     3.29     $    4.65     $     (1.36 )        (29.2 )%

(1) Based on average monthly rig count data from Baker Hughes
(2) Source: Bloomberg

The average number of worldwide operating rigs increased during the first quarter of 2012 but declined during the second quarter of 2012 to end the period at a level slightly higher than the beginning of the year rig count level. Both quarterly movements were largely driven by seasonal trends in Canada. The first six months of 2011 reflected a similar trend. Increased U.S. activity levels accounted for over 80% of the average global rig count increase during the first . . .